FERC Form

THIS FILING IS

Item 1:

☑ An Initial (Original) Submission

OR

☐ Resubmission No.




FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report

These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature

Exact Legal Name of Respondent (Company)

Entergy Mississippi, LLC

Year/Period of Report

End of:

2024

/

Q4

INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

Purpose
FERC Form No. 1 (FERC Form 1) is an annual regulatory requirement for Major electric utilities, licensees and others (18 C.F.R. § 141.1). FERC Form No. 3-Q ( FERC Form 3-Q) is a quarterly regulatory requirement which supplements the annual financial reporting requirement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities, licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be non-confidential public use forms.
Who Must Submit
Each Major electric utility, licensee, or other, as classified in the Commission’s Uniform System of Accounts Prescribed for Public Utilities, Licensees, and Others Subject To the Provisions of The Federal Power Act (18 C.F.R. Part 101), must submit FERC Form 1 (18 C.F.R. § 141.1), and FERC Form 3-Q (18 C.F.R. § 141.400).
Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following:
1. one million megawatt hours of total annual sales,
2. 100 megawatt hours of annual sales for resale,
3. 500 megawatt hours of annual power exchanges delivered, or
4. 500 megawatt hours of annual wheeling for others (deliveries plus losses).

What and Where to Submit

Submit FERC Form Nos. 1 and 3-Q electronically through the eCollection portal at https://eCollection.ferc.gov, and according to the specifications in the Form 1 and 3-Q taxonomies.
The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings.
Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report to the Secretary of the Commission at:
Secretary
Federal Energy Regulatory Commission 888 First Street, NE
Washington, DC 20426

For the CPA Certification Statement, submit within 30 days after filing the FERC Form 1, a letter or report (not applicable to filers classified as Class C or Class D prior to January 1, 1984). The CPA Certification Statement can be either eFiled or mailed to the Secretary of the Commission at the address above.

The CPA Certification Statement should:

Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with the Commission's applicable Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and

Be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 41.10-41.12 for specific qualifications.)

Schedules	Pages
Comparative Balance Sheet	110-113
Statement of Income	114-117
Statement of Retained Earnings	118-119
Statement of Cash Flows	120-121
Notes to Financial Statements	122-123

The following format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained in the letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported.
“In connection with our regular examination of the financial statements of [COMPANY NAME] for the year ended on which we have reported separately under date of [DATE], we have also reviewed schedules [NAME OF SCHEDULES] of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.
Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.” The letter or report must state which, if any, of the pages above do not conform to the Commission’s requirements. Describe the discrepancies that exist.
Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. Further instructions are found on the Commission’s website at https://www.ferc.gov/ferc-online/ferc-online/frequently-asked-questions-faqs-efilingferc-online.
Federal, State, and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q free of charge from https://www.ferc.gov/general-information-0/electric-industry-forms.

When to Submit
FERC Forms 1 and 3-Q must be filed by the following schedule:
1. FERC Form 1 for each year ending December 31 must be filed by April 18th of the following year (18 CFR § 141.1), and
2. FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. § 141.400).
Where to Send Comments on Public Reporting Burden.
The public reporting burden for the FERC Form 1 collection of information is estimated to average 1,168 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the FERC Form 3-Q collection of information is estimated to average 168 hours per response.
Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S.C. § 3512 (a)).

GENERAL INSTRUCTIONS

Prepare this report in conformity with the Uniform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and phrases in accordance with the USofA.
Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts.
Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact.
For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3.
Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below).
Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
For any resubmissions, please explain the reason for the resubmission in a footnote to the data field.
Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used.
Schedule specific instructions are found in the applicable taxonomy and on the applicable blank rendered form.

Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:

FNS - Firm Network Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. "Self" means the respondent.

FNO - Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff.

LFP - for Long-Term Firm Point-to-Point Transmission Reservations. "Long-Term" means one year or longer and” firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Reservations" are described in Order No. 888 and the Open Access Transmission Tariff. For all transactions identified as LFP, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally cancel the contract.

OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and “firm” means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.

SFP - Short-Term Firm Point-to-Point Transmission Reservations. Use this classification for all firm point-to-point transmission reservations, where the duration of each period of reservation is less than one-year.

NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions.

OS - Other Transmission Service. Use this classification only for those services which can not be placed in the above-mentioned classifications, such as all other service regardless of the length of the contract and service FERC Form. Describe the type of service in a footnote for each entry.

AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment.

DEFINITIONS

Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization.
Respondent -- The person, corporation, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is made.

EXCERPTS FROM THE LAW

Federal Power Act, 16 U.S.C. § 791a-825r

Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:

’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined;
'Person' means an individual or a corporation;
'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof;

'municipality means a city, county, irrigation district, drainage district, or other political subdivision or agency of a State competent under the Laws thereof to carry and the business of developing, transmitting, unitizing, or distributing power; ......

"project' means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the primary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit;

"Sec. 4. The Commission is hereby authorized and empowered

'To make investigations and to collect and record data concerning the utilization of the water 'resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development costs, and relation to markets of power sites; ... to the extent the Commission may deem necessary or useful for the purposes of this Act."

"Sec. 304.

Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the Commission may by rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the proper administration of this Act. The Commission may prescribe the manner and FERC Form in which such reports shall be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies*.10

"Sec. 309.

The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and the time within which they shall be field..."

GENERAL PENALTIES

The Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).

FERC FORM NO.

1

REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER

IDENTIFICATION

01 Exact Legal Name of Respondent

Entergy Mississippi, LLC

02 Year/ Period of Report

End of:

2024

/

Q4

03 Previous Name and Date of Change (If name changed during year)

/

04 Address of Principal Office at End of Period (Street, City, State, Zip Code)

308 East Pearl Street, Jackson, Mississippi 39201

05 Name of Contact Person

Gina G. Bellott

06 Title of Contact Person

Sr. Staff Accountant

07 Address of Contact Person (Street, City, State, Zip Code)

639 Loyola Avenue, New Orleans, Louisiana 70113

08 Telephone of Contact Person, Including Area Code

(504) 858-3276

09 This Report is An Original / A Resubmission

(1)

☑ An Original

(2)

☐ A Resubmission

10 Date of Report (Mo, Da, Yr)

04/15/2025

Annual Corporate Officer Certification

The undersigned officer certifies that:

I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts.

01 Name

Reginald T. Jackson

02 Title

Sr VP & Chief Accounting Officer

03 Signature

Reginald T. Jackson

04 Date Signed (Mo, Da, Yr)

04/15/2025

Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

LIST OF SCHEDULES (Electric Utility)
Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".
Line No.	Title of Schedule (a)	Reference Page No. (b)	Remarks (c)
	ScheduleIdentificationAbstract Identification	1
	ScheduleListOfSchedulesAbstract List of Schedules	2
1	ScheduleGeneralInformationAbstract General Information	101
2	ScheduleControlOverRespondentAbstract Control Over Respondent	102
3	ScheduleCorporationsControlledByRespondentAbstract Corporations Controlled by Respondent	103
4	ScheduleOfficersAbstract Officers	104
5	ScheduleDirectorsAbstract Directors	105
6	ScheduleInformationOnFormulaRatesAbstract Information on Formula Rates	106
7	ScheduleImportantChangesDuringTheQuarterYearAbstract Important Changes During the Year	108
8	ScheduleComparativeBalanceSheetAbstract Comparative Balance Sheet	110
9	ScheduleStatementOfIncomeAbstract Statement of Income for the Year	114
10	ScheduleRetainedEarningsAbstract Statement of Retained Earnings for the Year	118
12	ScheduleStatementOfCashFlowsAbstract Statement of Cash Flows	120
12	ScheduleNotesToFinancialStatementsAbstract Notes to Financial Statements	122
13	ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract Statement of Accum Other Comp Income, Comp Income, and Hedging Activities	122a	NA
14	ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep	200
15	ScheduleNuclearFuelMaterialsAbstract Nuclear Fuel Materials	202	NA
16	ScheduleElectricPlantInServiceAbstract Electric Plant in Service	204
17	ScheduleElectricPropertyLeasedToOthersAbstract Electric Plant Leased to Others	213	NA
18	ScheduleElectricPlantHeldForFutureUseAbstract Electric Plant Held for Future Use	214
19	ScheduleConstructionWorkInProgressElectricAbstract Construction Work in Progress-Electric	216
20	ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract Accumulated Provision for Depreciation of Electric Utility Plant	219
21	ScheduleInvestmentsInSubsidiaryCompaniesAbstract Investment of Subsidiary Companies	224
22	ScheduleMaterialsAndSuppliesAbstract Materials and Supplies	227
23	ScheduleAllowanceInventoryAbstract Allowances	228
24	ScheduleExtraordinaryPropertyLossesAbstract Extraordinary Property Losses	230a	NA
25	ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract Unrecovered Plant and Regulatory Study Costs	230b	NA
26	ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract Transmission Service and Generation Interconnection Study Costs	231	NA
27	ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets	232
28	ScheduleMiscellaneousDeferredDebitsAbstract Miscellaneous Deferred Debits	233
29	ScheduleAccumulatedDeferredIncomeTaxesAbstract Accumulated Deferred Income Taxes	234
30	ScheduleCapitalStockAbstract Capital Stock	250	NA
31	ScheduleOtherPaidInCapitalAbstract Other Paid-in Capital	253
32	ScheduleCapitalStockExpenseAbstract Capital Stock Expense	254b	NA
33	ScheduleLongTermDebtAbstract Long-Term Debt	256
34	ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax	261
35	ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract Taxes Accrued, Prepaid and Charged During the Year	262
36	ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract Accumulated Deferred Investment Tax Credits	266
37	ScheduleOtherDeferredCreditsAbstract Other Deferred Credits	269
38	ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract Accumulated Deferred Income Taxes-Accelerated Amortization Property	272	NA
39	ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract Accumulated Deferred Income Taxes-Other Property	274
40	ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract Accumulated Deferred Income Taxes-Other	276
41	ScheduleOtherRegulatoryLiabilitiesAbstract Other Regulatory Liabilities	278
42	ScheduleElectricOperatingRevenuesAbstract Electric Operating Revenues	300
43	ScheduleRegionalTransmissionServiceRevenuesAbstract Regional Transmission Service Revenues (Account 457.1)	302
44	ScheduleSalesOfElectricityByRateSchedulesAbstract Sales of Electricity by Rate Schedules	304
45	ScheduleSalesForResaleAbstract Sales for Resale	310
46	ScheduleElectricOperationsAndMaintenanceExpensesAbstract Electric Operation and Maintenance Expenses	320
47	SchedulePurchasedPowerAbstract Purchased Power	326
48	ScheduleTransmissionOfElectricityForOthersAbstract Transmission of Electricity for Others	328
49	ScheduleTransmissionOfElectricityByIsoOrRtoAbstract Transmission of Electricity by ISO/RTOs	331	NA
50	ScheduleTransmissionOfElectricityByOthersAbstract Transmission of Electricity by Others	332
51	ScheduleMiscellaneousGeneralExpensesAbstract Miscellaneous General Expenses-Electric	335
52	ScheduleDepreciationDepletionAndAmortizationAbstract Depreciation and Amortization of Electric Plant (Account 403, 404, 405)	336
53	ScheduleRegulatoryCommissionExpensesAbstract Regulatory Commission Expenses	350
54	ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract Research, Development and Demonstration Activities	352
55	ScheduleDistributionOfSalariesAndWagesAbstract Distribution of Salaries and Wages	354
56	ScheduleCommonUtilityPlantAndExpensesAbstract Common Utility Plant and Expenses	356	NA
57	ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract Amounts included in ISO/RTO Settlement Statements	397
58	SchedulePurchasesSalesOfAncillaryServicesAbstract Purchase and Sale of Ancillary Services	398
59	ScheduleMonthlyTransmissionSystemPeakLoadAbstract Monthly Transmission System Peak Load	400
60	ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract Monthly ISO/RTO Transmission System Peak Load	400a	NA
61	ScheduleElectricEnergyAccountAbstract Electric Energy Account	401a
62	ScheduleMonthlyPeakAndOutputAbstract Monthly Peaks and Output	401b
63	ScheduleSteamElectricGeneratingPlantStatisticsAbstract Steam Electric Generating Plant Statistics	402
64	ScheduleHydroelectricGeneratingPlantStatisticsAbstract Hydroelectric Generating Plant Statistics	406	NA
65	SchedulePumpedStorageGeneratingPlantStatisticsAbstract Pumped Storage Generating Plant Statistics	408	NA
66	ScheduleGeneratingPlantStatisticsAbstract Generating Plant Statistics Pages	410	NA
66.1	ScheduleEnergyStorageOperationsLargePlantsAbstract Energy Storage Operations (Large Plants)	414	NA
66.2	ScheduleEnergyStorageOperationsSmallPlantsAbstract Energy Storage Operations (Small Plants)	419	NA
67	ScheduleTransmissionLineStatisticsAbstract Transmission Line Statistics Pages	422
68	ScheduleTransmissionLinesAddedAbstract Transmission Lines Added During Year	424	NA
69	ScheduleSubstationsAbstract Substations	426
70	ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract Transactions with Associated (Affiliated) Companies	429
71	FootnoteDataAbstract Footnote Data	450	NA
	StockholdersReportsAbstract Stockholders' Reports (check appropriate box)
	Stockholders' Reports Check appropriate box: ☐ Two copies will be submitted ☑ No annual report to stockholders is prepared

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

GENERAL INFORMATION
1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept. Reginald T. Jackson Senior Vice President and Chief Accounting Officer 639 Loyola Avenue, New Orleans, LA 70113
2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized. State of Incorporation: TX Date of Incorporation: 2018-09-17 Incorporated Under Special Law:
3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased. N/A (a) Name of Receiver or Trustee Holding Property of the Respondent: (b) Date Receiver took Possession of Respondent Property: (c) Authority by which the Receivership or Trusteeship was created: (d) Date when possession by receiver or trustee ceased:
4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated. Mississippi - Electric Utility Service
5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements? (1) ☐ Yes (2) ☑ No

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

CONTROL OVER RESPONDENT
1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust.

As of December 31, 2024, all of the common membership interests in Entergy Arkansas are held by Entergy Utility Holding Company. As of December 31, 2024, Entergy Utility Holding Company's membership interests are held by: Entergy Corporation 3.7% 459,503 shares Entergy Utility Affiliates 23.4% multiple securities Entergy Utility Assets 31.2% 3,886,154 shares Entergy Utility Enterprises 13.2% 1,640,560 shares Entergy Utility Group 2.8% 350,173 shares EUHC Holdings 24.2% 3,006,086 shares Unaffiliated third parties 1.5% multiple securities

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

CORPORATIONS CONTROLLED BY RESPONDENT
Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming any intermediaries involved. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests. Definitions See the Uniform System of Accounts for a definition of control. Direct control is that which is exercised without interposition of an intermediary. Indirect control is that which is exercised by the interposition of an intermediary which exercises direct control. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the Uniform System of Accounts, regardless of the relative voting rights of each party.
Line No.	NameOfCompanyControlledByRespondent Name of Company Controlled (a)	CompanyControlledByRespondentKindOfBusinessDescription Kind of Business (b)	VotingStockOwnedByRespondentPercentage Percent Voting Stock Owned (c)	FootnoteReferences Footnote Ref. (d)
1	Entergy Power & Light Company		100
2	The Light, Heat and Water Company of Jackson, Mississippi		100
3	Jackson Gas Light Company		100
4	Mississippi Power & Light Company		100
5	MS Sunflower Partnership, LLC		100

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

OFFICERS
Report below the name, title and salary for each executive officer whose salary is $50,000 or more. An "executive officer" of a respondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or function (such as sales, administration or finance), and any other person who performs similar policy making functions. If a change was made during the year in the incumbent of any position, show name and total remuneration of the previous incumbent, and the date the change in incumbency was made.
Line No.	OfficerTitle Title (a)	OfficerName Name of Officer (b)	OfficerSalary Salary for Year (c)	DateOfficerIncumbencyStarted Date Started in Period (d)	DateOfficerIncumbencyEnded Date Ended in Period (e)
1	President and Chief Executive Officer of Entergy Mississippi	Haley R. Fisackerly	452,266
2	Chairman of the Board and Chief Executive Officer of Entergy Corporation	Andrew S. Marsh	(a) 0
3	Executive Vice President and Chief Financial Officer	Kimberly A. Fontan	(b) 0
4	Executive Vice President and Chief Operating Officer of Entergy Corporation	Peter S. Norgeot, Jr.	(c) 0
5	Executive Vice President and General Counsel	Marcus V. Brown	(d) 0
6	Group President Utility Operations	Roderick K. West	(e) 0		2024-10-31
7	Senior Vice President and Chief Accounting Officer	Reginald T. Jackson	(f) 0
8	Vice President and General Tax Counsel	Steven W. Brady	(g) 0

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

(b) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

(c) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

(d) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

(e) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

(f) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

(g) Concept: OfficerSalary

Salary not presented as individual was compensated by other System companies and not by Entergy Mississippi.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

DIRECTORS
Report below the information called for concerning each director of the respondent who held office at any time during the year. Include in column (a), name and abbreviated titles of the directors who are officers of the respondent. Provide the principle place of business in column (b), designate members of the Executive Committee in column (c), and the Chairman of the Executive Committee in column (d).
Line No.	NameAndTitleOfDirector Name (and Title) of Director (a)	PrincipalBusinessAddress Principal Business Address (b)	MemberOfTheExecutiveCommittee Member of the Executive Committee (c)	ChairmanOfTheExecutiveCommittee Chairman of the Executive Committee (d)
1	Haley R. Fisackerly - President and Chief Executive Officer of Entergy Mississippi	308 East Pearl Street, Jackson, MS 39201	true	false
2	Kimberly A. Fontan - Executive Vice President and Chief Financial Officer	639 Loyola Avenue, New Orleans, LA 70113	true	false
3	Peter S. Norgeot, Jr. - Executive Vice President and Chief Operating Officer of Entergy Corporation	639 Loyola Avenue, New Orleans, LA 70113	true	false

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

INFORMATION ON FORMULA RATES
Does the respondent have formula rates?		☑ Yes ☐ No
Please list the Commission accepted formula rates including FERC Rate Schedule or Tariff Number and FERC proceeding (i.e. Docket No) accepting the rate(s) or changes in the accepted rate.
Line No.	RateScheduleTariffNumber FERC Rate Schedule or Tariff Number (a)	ProceedingDocketNumber FERC Proceeding (b)
1	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tariff (UPS/DPPT or MSS-4 Replacement Tariff) - Baseline Tariff	Docket No. ER13-1508
2	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tariff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER16-2199
3	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tariff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER18-1247
4	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tariff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER19-747
5	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tariff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER21-915
6	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tariff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER21-1720
7	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tariff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER21-1997
8	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tariff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER21-2169
9	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tariff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER22-489
10	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tariff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER22-2332
11	Midcontinent Indepedent System Operator (MISO) FERC Electric Tariff - Fifth Revised Volume 1	Docket No. ER13-948
12	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER14-649
13	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER15-358
14	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER15-1436
15	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER16-227
16	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER16-1322
17	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-215
18	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-1549
19	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-1777
20	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-2579
21	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER18-1260
22	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER18-1982
23	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER19-652
24	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER19-1503
25	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER17-827
26	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER20-1449
27	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER20-1472
28	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER21-200
29	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER21-262
30	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER21-2693
31	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER22-1602
32	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER22-2202
33	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER22-2562
34	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER23-2707
35	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tariff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER23-1228
36	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tariff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER23-2821
37	Rate Schedule No. 705: Entergy OpCos, Unit Power Sales/Designated Power Purchase Tariff (UPS/DPPT or MSS-4 Replacement Tariff) - Amended Tariff	Docket No. ER24-2468
38	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-224
39	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-430
40	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-1029
41	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-1055
42	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-1179
43	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-1191
44	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-1204
45	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-1377
46	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-1538
47	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-1634
48	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-1905
49	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-2871
50	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-3067
51	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-3138
52	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER24-3141
53	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER25-324
54	Midcontinent Indepedent System Operator (MISO)-FERC Electric Tariff	Docket No. ER25-507

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding
Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)?			☑ Yes ☐ No
If yes, provide a listing of such filings as contained on the Commission's eLibrary website.
Line No.	AccessionNumber Accession No. (a)	DocumentDate Document Date / Filed Date (b)	DocketNumber Docket No. (c)	DescriptionOfFiling Description (d)	RateScheduleTariffNumber Formula Rate FERC Rate Schedule Number or Tariff Number (e)
1	20240315-2179	03/15/2024	ER24-1529	(a) EML Annual Informational MISO Attachment O Transmission Formula Rate Update
2	20240329-5493	03/29/2024	ER24-1673	MSS-4R Tariff Formula Rate Informational Filing

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: DescriptionOfFiling

Pursuant to the Federal Energy Regulatory Commission’s orders in Docket Nos. EL12-35 and ER13-2379 and the Annual Update, Information Exchange, and Challenge Procedures of the Entergy Operating Companies set forth in Attachment O of the Midcontinent Independent System Operator, Inc.’s Open Access Transmission, Energy and Operating Reserve Markets Tariff, Entergy Services shall submit an annual Informational Filing on March 15 based on data for the second preceding calendar year data. The 2023 update was filed on March 15, 2024 in Docket No. ER24-1529. This Informational Filing is not a rate filing. It shows the development of the Entergy Operating Companies’ annual transmission revenue requirements for billing June 1, 2023 through May 31, 2024 through the application of data for Calendar Year 2022 under the Attachment O MISO Tariff.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

INFORMATION ON FORMULA RATES - Formula Rate Variances
If a respondent does not submit such filings then indicate in a footnote to the applicable Form 1 schedule where formula rate inputs differ from amounts reported in the Form 1. The footnote should provide a narrative description explaining how the "rate" (or billing) was derived if different from the reported amount in the Form 1. The footnote should explain amounts excluded from the ratebase or where labor or other allocation factors, operating expenses, or other items impacting formula rate inputs differ from amounts reported in Form 1 schedule amounts. Where the Commission has provided guidance on formula rate inputs, the specific proceeding should be noted in the footnote.
Line No.	PageNumberOfFormulaRateVariances Page No(s). (a)	ScheduleOfFormulaRateVariances Schedule (b)	ColumnOfFormulaRateVariances Column (c)	LineNumberOfFormulaRateVariances Line No. (d)
1		NONE

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

IMPORTANT CHANGES DURING THE QUARTER/YEAR
Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments. State the estimated annual effect and nature of any important wage scale changes during the year. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Pages 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest. (Reserved.) If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.

1.None
2. None
3. None
4. None
5. None
6. See Entergy Mississippi's 2024 FERC Form 1 Notes to Financial Statements, Notes 4, 5, and 8.
7. None
8. Transmission, distribution, and utility support employees are represented by the International Brotherhood of Electrical Workers AFL-CIO, Local Unions 605 and 985. The Company and the Union agreed to a contract effective October 15, 2022 through October 15, 2025. Effective October 16, 2024, the wage increase was 2.5%. Fossil operating employees are represented by the International Brotherhood of Electrical Workers AFL-CIO, Local Unions 605 and 985. The Company and the Union agreed to a contract effective April 16, 2022 through May 31, 2028. Effective April 16, 2024, the wage increase was 3.5%. Effective April 1, 2024, executive and senior management, middle management, professionals, and non-represented operating, maintenance, and support staff pay increases averaged approximately 4.0%.
9. See Entergy Mississippi’s 2024 FERC Form 1 Notes to Financial Statements, Notes 2 and 8.
10. None
12. See Entergy Mississippi's 2024 FERC Form 1 Notes to Financial Statements.
13. See Entergy Mississippi’s 2024 FERC Form 1 pages 104 and 105 for Officer and Director changes that occurred in 2024.
14. Not applicable

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlant Utility Plant (101-106, 114)	200	7,711,357,508	7,306,663,808
3	ConstructionWorkInProgress Construction Work in Progress (107)	200	510,924,980	157,119,085
4	UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3)		8,222,282,488	7,463,782,893
5	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)	200	(a) 2,322,111,180	(b) 2,155,897,819
6	UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5)		5,900,171,308	5,307,885,074
7	NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)	202
8	NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly Nuclear Fuel Materials and Assemblies-Stock Account (120.2)
9	NuclearFuelAssembliesInReactorMajorOnly Nuclear Fuel Assemblies in Reactor (120.3)
10	SpentNuclearFuelMajorOnly Spent Nuclear Fuel (120.4)
11	NuclearFuelUnderCapitalLeases Nuclear Fuel Under Capital Leases (120.6)
12	AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)	202
13	NuclearFuelNet Net Nuclear Fuel (Enter Total of lines 7-11 less 12)
14	UtilityPlantAndNuclearFuelNet Net Utility Plant (Enter Total of lines 6 and 13)		5,900,171,308	5,307,885,074
15	OtherElectricPlantAdjustments Utility Plant Adjustments (116)
16	GasStoredUndergroundNoncurrent Gas Stored Underground - Noncurrent (117)
17	OtherPropertyAndInvestmentsAbstract OTHER PROPERTY AND INVESTMENTS
18	NonutilityProperty Nonutility Property (121)		5,025,426	5,025,426
19	AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122)		543,468	528,511
20	InvestmentInAssociatedCompanies Investments in Associated Companies (123)
21	InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1)	224	95,281,478	101,256,108
23	NoncurrentPortionOfAllowances Noncurrent Portion of Allowances	228
24	OtherInvestments Other Investments (124)
25	SinkingFunds Sinking Funds (125)
26	DepreciationFund Depreciation Fund (126)
27	AmortizationFundFederal Amortization Fund - Federal (127)
28	OtherSpecialFunds Other Special Funds (128)		880,009	656,004
29	SpecialFunds Special Funds (Non Major Only) (129)
30	DerivativeInstrumentAssetsLongTerm Long-Term Portion of Derivative Assets (175)
31	DerivativeInstrumentAssetsHedgesLongTerm Long-Term Portion of Derivative Assets - Hedges (176)
32	OtherPropertyAndInvestments TOTAL Other Property and Investments (Lines 18-21 and 23-31)		100,643,445	106,409,027
33	CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS
34	CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130)
35	Cash Cash (131)		182,227	28,466
36	SpecialDeposits Special Deposits (132-134)
37	WorkingFunds Working Fund (135)		5	43
38	TemporaryCashInvestments Temporary Cash Investments (136)		151,903,633
39	NotesReceivable Notes Receivable (141)
40	CustomerAccountsReceivable Customer Accounts Receivable (142)		97,609,011	121,388,981
41	OtherAccountsReceivable Other Accounts Receivable (143)		25,144,370	17,695,868
42	AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144)		2,172,329	3,311,737
43	NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145)
44	AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146)		23,916,759	4,997,470
45	FuelStock Fuel Stock (151)	227	14,948,488	16,188,254
46	FuelStockExpensesUndistributed Fuel Stock Expenses Undistributed (152)	227	10,322
47	Residuals Residuals (Elec) and Extracted Products (153)	227
48	PlantMaterialsAndOperatingSupplies Plant Materials and Operating Supplies (154)	227	106,718,875	89,885,458
49	Merchandise Merchandise (155)	227
50	OtherMaterialsAndSupplies Other Materials and Supplies (156)	227
51	NuclearMaterialsHeldForSale Nuclear Materials Held for Sale (157)	202/227
52	AllowanceInventoryAndWithheld Allowances (158.1 and 158.2)	228	4,603	7,406
53	NoncurrentPortionOfAllowances (Less) Noncurrent Portion of Allowances	228
54	StoresExpenseUndistributed Stores Expense Undistributed (163)	227	6,536,867	5,640,795
55	GasStoredCurrent Gas Stored Underground - Current (164.1)
56	LiquefiedNaturalGasStoredAndHeldForProcessing Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57	Prepayments Prepayments (165)		18,511,989	19,200,941
58	AdvancesForGas Advances for Gas (166-167)
59	InterestAndDividendsReceivable Interest and Dividends Receivable (171)		573,729	10,651
60	RentsReceivable Rents Receivable (172)
61	AccruedUtilityRevenues Accrued Utility Revenues (173)		75,740,265	71,465,082
62	MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174)		5,507,260	8,841
63	DerivativeInstrumentAssets Derivative Instrument Assets (175)		1,550,310	1,358,301
64	DerivativeInstrumentAssetsLongTerm (Less) Long-Term Portion of Derivative Instrument Assets (175)
65	DerivativeInstrumentAssetsHedges Derivative Instrument Assets - Hedges (176)
66	DerivativeInstrumentAssetsHedgesLongTerm (Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67	CurrentAndAccruedAssets Total Current and Accrued Assets (Lines 34 through 66)		526,686,384	344,547,052
68	DeferredDebitsAbstract DEFERRED DEBITS
69	UnamortizedDebtExpense Unamortized Debt Expenses (181)		23,718,905	21,332,182
70	ExtraordinaryPropertyLosses Extraordinary Property Losses (182.1)	230a
71	UnrecoveredPlantAndRegulatoryStudyCosts Unrecovered Plant and Regulatory Study Costs (182.2)	230b
72	OtherRegulatoryAssets Other Regulatory Assets (182.3)	232	344,340,530	392,003,456
73	PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183)		8,689,703	9,958,284
74	PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges Preliminary Natural Gas Survey and Investigation Charges 183.1)
75	OtherPreliminarySurveyAndInvestigationCharges Other Preliminary Survey and Investigation Charges (183.2)
76	ClearingAccounts Clearing Accounts (184)		32,690	139,828
77	TemporaryFacilities Temporary Facilities (185)
78	MiscellaneousDeferredDebits Miscellaneous Deferred Debits (186)	233	54,129,141	2,690,236
79	DeferredLossesFromDispositionOfUtilityPlant Def. Losses from Disposition of Utility Plt. (187)
80	ResearchDevelopmentAndDemonstrationExpenditures Research, Devel. and Demonstration Expend. (188)	352
81	UnamortizedLossOnReacquiredDebt Unamortized Loss on Reaquired Debt (189)		9,087,393	9,975,768
82	AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190)	234	46,220,577	53,598,274
83	UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191)
84	DeferredDebits Total Deferred Debits (lines 69 through 83)		486,153,559	489,418,372
85	AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84)		7,013,654,696	6,248,259,525

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility

Includes a debit balance for removal costs of $184,788,177.

(b) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility

Includes a debit balance for removal costs of $186,178,032.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	ProprietaryCapitalAbstract PROPRIETARY CAPITAL
2	CommonStockIssued Common Stock Issued (201)	250
3	PreferredStockIssued Preferred Stock Issued (204)	250
4	CapitalStockSubscribed Capital Stock Subscribed (202, 205)
5	StockLiabilityForConversion Stock Liability for Conversion (203, 206)
6	PremiumOnCapitalStock Premium on Capital Stock (207)
7	OtherPaidInCapital Other Paid-In Capital (208-211)	253	329,266,361	329,266,361
8	InstallmentsReceivedOnCapitalStock Installments Received on Capital Stock (212)	252
9	DiscountOnCapitalStock (Less) Discount on Capital Stock (213)	254
10	CapitalStockExpense (Less) Capital Stock Expense (214)	254b
11	RetainedEarnings Retained Earnings (215, 215.1, 216)	118	2,084,050,162	1,865,529,398
12	UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1)	118	11,720,062	4,400,773
13	ReacquiredCapitalStock (Less) Reacquired Capital Stock (217)	250
14	NoncorporateProprietorship Noncorporate Proprietorship (Non-major only) (218)
15	AccumulatedOtherComprehensiveIncome Accumulated Other Comprehensive Income (219)	122(a)(b)
16	ProprietaryCapital Total Proprietary Capital (lines 2 through 15)		2,401,596,461	2,190,394,986
17	LongTermDebtAbstract LONG-TERM DEBT
18	Bonds Bonds (221)	256	2,445,000,000	2,245,000,000
19	ReacquiredBonds (Less) Reacquired Bonds (222)	256
20	AdvancesFromAssociatedCompanies Advances from Associated Companies (223)	256
21	OtherLongTermDebt Other Long-Term Debt (224)	256
22	UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225)		11,347,495	11,804,774
23	UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226)		6,064,129	6,258,223
24	LongTermDebt Total Long-Term Debt (lines 18 through 23)		2,450,283,366	2,250,546,551
25	OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES
26	ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227)		32,506,276	26,501,028
27	AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1)		41,044,689	30,995,974
28	AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2)		6,151,177	4,356,054
29	AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3)		2,962,387	(a) 41,987,676
30	AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4)		4,000	4,000
31	AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229)
32	LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities
33	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges
34	AssetRetirementObligations Asset Retirement Obligations (230)		20,816,296	8,229,011
35	OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34)		103,484,825	28,098,391
36	CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES
37	NotesPayable Notes Payable (231)
38	AccountsPayable Accounts Payable (232)		283,641,478	92,322,729
39	NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233)
40	AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234)		58,072,646	133,829,288
41	CustomerDeposits Customer Deposits (235)		94,008,892	92,637,435
42	TaxesAccrued Taxes Accrued (236)	262	181,996,085	113,909,268
43	InterestAccrued Interest Accrued (237)		23,866,686	23,636,861
44	DividendsDeclared Dividends Declared (238)
45	MaturedLongTermDebt Matured Long-Term Debt (239)
46	MaturedInterest Matured Interest (240)
47	TaxCollectionsPayable Tax Collections Payable (241)		2,742,683	2,863,999
48	MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242)		3,172,910	5,435,293
49	ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243)		10,630,219	9,114,288
50	DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244)		498,194	10,145,279
51	LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities
52	DerivativeInstrumentLiabilitiesHedges Derivative Instrument Liabilities - Hedges (245)
53	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges (Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54	CurrentAndAccruedLiabilities Total Current and Accrued Liabilities (lines 37 through 53)		658,629,793	483,894,440
55	DeferredCreditsAbstract DEFERRED CREDITS
56	CustomerAdvancesForConstruction Customer Advances for Construction (252)		112,617,825	32,659,183
57	AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255)	266	13,446,466	13,810,508
58	DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256)
59	OtherDeferredCredits Other Deferred Credits (253)	269	1,906,094	19,554,236
60	OtherRegulatoryLiabilities Other Regulatory Liabilities (254)	278	370,601,011	360,097,781
61	UnamortizedGainOnReacquiredDebt Unamortized Gain on Reacquired Debt (257)
62	AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty Accum. Deferred Income Taxes-Accel. Amort.(281)	272
63	AccumulatedDeferredIncomeTaxesOtherProperty Accum. Deferred Income Taxes-Other Property (282)		843,629,552	800,329,215
64	AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283)		61,271,491	68,874,234
65	DeferredCredits Total Deferred Credits (lines 56 through 64)		1,399,660,251	1,295,325,157
66	LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)		7,013,654,696	6,248,259,525

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: AccumulatedProvisionForPensionsAndBenefits

Includes a debit balance of $44,318,000 for OPEB that is classified as a miscellaneous deferred debit in 2024.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

STATEMENT OF INCOME
Quarterly Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter. If additional columns are needed, place them in a footnote. Annual or Quarterly if applicable Do not report fourth quarter data in columns (e) and (f) Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above. Use page 122 for important notes regarding the statement of income for any account thereof. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.	Title of Account (a)	(Ref.) Page No. (b)	Total Current Year to Date Balance for Quarter/Year (c)	Total Prior Year to Date Balance for Quarter/Year (d)	Current 3 Months Ended - Quarterly Only - No 4th Quarter (e)	Prior 3 Months Ended - Quarterly Only - No 4th Quarter (f)	Electric Utility Current Year to Date (in dollars) (g)	Electric Utility Previous Year to Date (in dollars) (h)	Gas Utiity Current Year to Date (in dollars) (i)	Gas Utility Previous Year to Date (in dollars) (j)	Other Utility Current Year to Date (in dollars) (k)	Other Utility Previous Year to Date (in dollars) (l)
1	UtilityOperatingIncomeAbstract UTILITY OPERATING INCOME
2	OperatingRevenues Operating Revenues (400)	300	1,761,905,949	1,796,819,262			1,761,905,949	1,796,819,262
3	OperatingExpensesAbstract Operating Expenses
4	OperationExpense Operation Expenses (401)	320	793,161,602	1,083,824,007			793,161,602	1,083,824,007
5	MaintenanceExpense Maintenance Expenses (402)	320	65,494,164	85,609,970			65,494,164	85,609,970
6	DepreciationExpense Depreciation Expense (403)	336	234,184,841	230,361,502			234,184,841	230,361,502
7	DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1)	336	1,504,443	35,671			1,504,443	35,671
8	AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405)	336	28,468,966	25,665,402			28,468,966	25,665,402
9	AmortizationOfElectricPlantAcquisitionAdjustments Amort. of Utility Plant Acq. Adj. (406)	336	2,603,364	2,641,604			2,603,364	2,641,604
10	AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)
11	AmortizationOfConversionExpenses Amort. of Conversion Expenses (407.2)
12	RegulatoryDebits Regulatory Debits (407.3)		69,683,166	38,042,155			69,683,166	38,042,155
13	RegulatoryCredits (Less) Regulatory Credits (407.4)		39,944,092	158,534,821			39,944,092	158,534,821
14	TaxesOtherThanIncomeTaxesUtilityOperatingIncome Taxes Other Than Income Taxes (408.1)	262	160,922,483	145,632,431			160,922,483	145,632,431
15	IncomeTaxesOperatingIncome Income Taxes - Federal (409.1)	262	38,809,732	99,452,892			38,809,732	99,452,892
16	IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1)	262	2,419,988	24,269,432			2,419,988	24,269,432
17	ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1)	234, 272	261,941,175	818,172,888			261,941,175	818,172,888
18	ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1)	234, 272	223,508,831	636,657,862			223,508,831	636,657,862
19	InvestmentTaxCreditAdjustments Investment Tax Credit Adj. - Net (411.4)	266	379,910	795,902			379,910	795,902
20	GainsFromDispositionOfPlant (Less) Gains from Disp. of Utility Plant (411.6)
21	LossesFromDispositionOfServiceCompanyPlant Losses from Disp. of Utility Plant (411.7)
22	GainsFromDispositionOfAllowances (Less) Gains from Disposition of Allowances (411.8)			33				33
23	LossesFromDispositionOfAllowances Losses from Disposition of Allowances (411.9)
24	AccretionExpense Accretion Expense (411.10)		734,603	431,903			734,603	431,903
25	UtilityOperatingExpenses TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)		1,396,095,694	1,510,706,591			1,396,095,694	1,510,706,591
27	NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25)		365,810,255	286,112,671			365,810,255	286,112,671
28	OtherIncomeAndDeductionsAbstract Other Income and Deductions
29	OtherIncomeAbstract Other Income
30	NonutilityOperatingIncomeAbstract Nonutilty Operating Income
31	RevenuesFromMerchandisingJobbingAndContractWork Revenues From Merchandising, Jobbing and Contract Work (415)
32	CostsAndExpensesOfMerchandisingJobbingAndContractWork (Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)
33	RevenuesFromNonutilityOperations Revenues From Nonutility Operations (417)
34	ExpensesOfNonutilityOperations (Less) Expenses of Nonutility Operations (417.1)		14,957	14,957
35	NonoperatingRentalIncome Nonoperating Rental Income (418)
36	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1)	119	7,319,289	4,613,522
37	InterestAndDividendIncome Interest and Dividend Income (419)		3,092,979	1,790,811
38	AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1)		9,095,371	8,551,586
39	MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421)		2,209,191	1,787,927
40	GainOnDispositionOfProperty Gain on Disposition of Property (421.1)		15,092
41	OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40)		7,078,387	7,501,845
42	OtherIncomeDeductionsAbstract Other Income Deductions
43	LossOnDispositionOfProperty Loss on Disposition of Property (421.2)		443,868	268,683
44	MiscellaneousAmortization Miscellaneous Amortization (425)
45	Donations Donations (426.1)		997,165	1,066,235
46	LifeInsurance Life Insurance (426.2)
47	Penalties Penalties (426.3)		89,127	52,152
48	ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4)		1,943,845	2,195,587
49	OtherDeductions Other Deductions (426.5)		5,135,099	3,029,969
50	OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49)		8,609,104	6,612,626
51	TaxesApplicableToOtherIncomeAndDeductionsAbstract Taxes Applic. to Other Income and Deductions
52	TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions Taxes Other Than Income Taxes (408.2)	262
53	IncomeTaxesFederal Income Taxes-Federal (409.2)	262	52,999	1,305,496
54	IncomeTaxesOther Income Taxes-Other (409.2)	262	13,283	327,192
55	ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2)	234, 272
56	ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions (Less) Provision for Deferred Income Taxes-Cr. (411.2)	234, 272
57	InvestmentTaxCreditAdjustmentsNonutilityOperations Investment Tax Credit Adj.-Net (411.5)
58	InvestmentTaxCredits (Less) Investment Tax Credits (420)
59	TaxesOnOtherIncomeAndDeductions TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)		66,282	1,632,688
60	NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59)		1,464,435	2,521,907
61	InterestChargesAbstract Interest Charges
62	InterestOnLongTermDebt Interest on Long-Term Debt (427)		96,155,734	91,374,316
63	AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428)		1,925,256	2,106,704
64	AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1)		889,445	917,109
65	AmortizationOfPremiumOnDebtCredit (Less) Amort. of Premium on Debt-Credit (429)		457,279	457,279
66	AmortizationOfGainOnReacquiredDebtCredit (Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67	InterestOnDebtToAssociatedCompanies Interest on Debt to Assoc. Companies (430)		1,943,355	1,492,102
68	OtherInterestExpense Other Interest Expense (431)		11,574,460	3,424,195
69	AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)		3,519,959	3,479,323
70	NetInterestCharges Net Interest Charges (Total of lines 62 thru 69)		108,511,012	95,377,824
71	IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70)		255,834,808	193,256,754
72	ExtraordinaryItemsAbstract Extraordinary Items
73	ExtraordinaryIncome Extraordinary Income (434)
74	ExtraordinaryDeductions (Less) Extraordinary Deductions (435)
75	NetExtraordinaryItems Net Extraordinary Items (Total of line 73 less line 74)
76	IncomeTaxesExtraordinaryItems Income Taxes-Federal and Other (409.3)	262	0
77	ExtraordinaryItemsAfterTaxes Extraordinary Items After Taxes (line 75 less line 76)
78	NetIncomeLoss Net Income (Total of line 71 and 77)		255,834,808	193,256,754

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

STATEMENT OF RETAINED EARNINGS
Do not report Lines 49-53 on the quarterly report. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b). State the purpose and amount for each reservation or appropriation of retained earnings. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order. Show dividends for each class and series of capital stock. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No.	Item (a)	Contra Primary Account Affected (b)	Current Quarter/Year Year to Date Balance (c)	Previous Quarter/Year Year to Date Balance (d)
	UnappropriatedRetainedEarningsAbstract UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1	UnappropriatedRetainedEarnings Balance-Beginning of Period		1,865,529,398	1,707,659,122
2	ChangesAbstract Changes
3	AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439)
4	AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit
9	AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439)
10	AdjustmentsToRetainedEarningsDebitAbstract Adjustments to Retained Earnings Debit
15	AdjustmentsToRetainedEarningsDebit TOTAL Debits to Retained Earnings (Acct. 439)
16	BalanceTransferredFromIncome Balance Transferred from Income (Account 433 less Account 418.1)		263,154,097	197,870,276
17	AppropriationsOfRetainedEarningsAbstract Appropriations of Retained Earnings (Acct. 436)
22	AppropriationsOfRetainedEarnings TOTAL Appropriations of Retained Earnings (Acct. 436)
23	DividendsDeclaredPreferredStockAbstract Dividends Declared-Preferred Stock (Account 437)
29	DividendsDeclaredPreferredStock TOTAL Dividends Declared-Preferred Stock (Acct. 437)
30	DividendsDeclaredCommonStockAbstract Dividends Declared-Common Stock (Account 438)
30.1	DividendsDeclaredCommonStock Common equity distributions	131	44,633,333	40,000,000
36	DividendsDeclaredCommonStock TOTAL Dividends Declared-Common Stock (Acct. 438)		44,633,333	40,000,000
37	TransfersFromUnappropriatedUndistributedSubsidiaryEarnings Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings
38	UnappropriatedRetainedEarnings Balance - End of Period (Total 1,9,15,16,22,29,36,37)		2,084,050,162	1,865,529,398
39	AppropriatedRetainedEarningsAbstract APPROPRIATED RETAINED EARNINGS (Account 215)
45	AppropriatedRetainedEarnings TOTAL Appropriated Retained Earnings (Account 215)
	AppropriatedRetainedEarningsAmortizationReserveFederalAbstract APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46	AppropriatedRetainedEarningsAmortizationReserveFederal TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)
47	AppropriatedRetainedEarningsIncludingReserveAmortization TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)
48	RetainedEarnings TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)		2,084,050,162	1,865,529,398
	UnappropriatedUndistributedSubsidiaryEarningsAbstract UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49	UnappropriatedUndistributedSubsidiaryEarnings Balance-Beginning of Year (Debit or Credit)		4,400,773	212,749
50	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings for Year (Credit) (Account 418.1)		7,319,289	4,613,522
51	DividendsReceived (Less) Dividends Received (Debit)
52	ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
53	UnappropriatedUndistributedSubsidiaryEarnings Balance-End of Year (Total lines 49 thru 52)		11,720,062	4,400,773

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

STATEMENT OF CASH FLOWS
Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.	Description (See Instructions No.1 for explanation of codes) (a)	Current Year to Date Quarter/Year (b)	Previous Year to Date Quarter/Year (c)
1	NetCashFlowFromOperatingActivitiesAbstract Net Cash Flow from Operating Activities
2	NetIncomeLoss Net Income (Line 78(c) on page 117)	255,834,808	193,256,754
3	NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income:
4	DepreciationAndDepletion Depreciation and Depletion	267,496,217	259,136,082
5	NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details)
5.1	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Amortization of debt discount and expense and premium on debt and amortization of loss on reacquired debt	2,814,701	3,023,813
8	DeferredIncomeTaxesNet Deferred Income Taxes (Net)	38,432,344	181,515,026
9	InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net)	379,910	795,902
10	NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables	7,215,142	3,627,421
11	NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory	16,500,045	11,831,249
12	NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory	2,803	3,401
13	NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses	257,647,561	214,189,987
14	NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets	47,662,926	122,676,352
15	NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities	10,503,230	74,010,348
16	AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction	9,095,371	8,551,586
17	UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies
18	OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote):
18.1	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other working capital	16,241,565	10,002,682
18.2	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other	141,929,676	35,646,582
22	NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)	703,463,165	556,231,209
24	CashFlowsFromInvestmentActivitiesAbstract Cash Flows from Investment Activities:
25	ConstructionAndAcquisitionOfPlantIncludingLandAbstract Construction and Acquisition of Plant (including land):
26	GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities Gross Additions to Utility Plant (less nuclear fuel)	699,704,362	553,244,089
27	GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel
28	GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant
29	GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant
30	AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction	9,095,371	8,551,586
31	OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote):
34	CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33)	690,608,991	544,692,503
36	AcquisitionOfOtherNoncurrentAssets Acquisition of Other Noncurrent Assets (d)
37	ProceedsFromDisposalOfNoncurrentAssets Proceeds from Disposal of Noncurrent Assets (d)
39	InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Investments in and Advances to Assoc. and Subsidiary Companies	1,000,000	5,557,754
40	ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies Contributions and Advances from Assoc. and Subsidiary Companies
41	DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract Disposition of Investments in (and Advances to)
42	DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
44	PurchaseOfInvestmentSecurities Purchase of Investment Securities (a)
45	ProceedsFromSalesOfInvestmentSecurities Proceeds from Sales of Investment Securities (a)
46	LoansMadeOrPurchased Loans Made or Purchased
47	CollectionsOnLoans Collections on Loans
49	NetIncreaseDecreaseInReceivablesInvestingActivities Net (Increase) Decrease in Receivables
50	NetIncreaseDecreaseInInventoryInvestingActivities Net (Increase) Decrease in Inventory
51	NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities Net (Increase) Decrease in Allowances Held for Speculation
52	NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities Net Increase (Decrease) in Payables and Accrued Expenses
53	OtherAdjustmentsToCashFlowsFromInvestmentActivities Other (provide details in footnote):
53.1	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Proceeds from sale of assets	818,377
53.2	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Changes in money pool receivable - net	15,217,554	26,879,352
53.3	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Other	(a) 959,987	742,064
53.4	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Receipts from storm reserve escrow account	735,981	34,545,081
57	CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)	706,232,174	489,567,888
59	CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities:
60	ProceedsFromIssuanceAbstract Proceeds from Issuance of:
61	ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b)	295,881,044	296,832,753
62	ProceedsFromIssuanceOfPreferredStockFinancingActivities Preferred Stock
63	ProceedsFromIssuanceOfCommonStockFinancingActivities Common Stock
64	OtherAdjustmentsToCashFlowsFromFinancingActivities Other (provide details in footnote):
66	NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c)
67	OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote):
70	CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69)	295,881,044	296,832,753
72	PaymentsForRetirementAbstract Payments for Retirement of:
73	PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b)	100,000,000	400,000,000
74	PaymentsForRetirementOfPreferredStockFinancingActivities Preferred Stock
75	PaymentsForRetirementOfCommonStockFinancingActivities Common Stock
76	OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities Other (provide details in footnote):
76.1	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Other	(b) 77,347,553	1,928,055
76.2	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Changes in money pool payable - net	73,768,813	73,768,813
76.3	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Common equity distributions paid	44,633,333	40,000,000
78	NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c)
80	DividendsOnPreferredStock Dividends on Preferred Stock
81	DividendsOnCommonStock Dividends on Common Stock
83	CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)	154,826,451	67,470,379
85	NetIncreaseDecreaseInCashAndCashEquivalentsAbstract Net Increase (Decrease) in Cash and Cash Equivalents
86	NetIncreaseDecreaseInCashAndCashEquivalents Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83)	152,057,442	807,058
88	CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period	28,423	835,481
90	CashAndCashEquivalents Cash and Cash Equivalents at End of Period	152,085,865	28,423

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities


Other investing activities include:
	2024	2023
Interest on prefunded property insurance escrow	($80,213)	($1,651,983)
Other special funds	—	(236)
Captive insurance deposit	(879,774)	910,155
Total	($959,987)	($742,064)

(b) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities


Other financing activities include:
	2024	2023
Customer Advances for Construction	$79,958,641	$4,095,636
Financing Leases	(2,611,088)	(2,167,581)

Total	$77,347,553	$1,928,055

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

NOTES TO FINANCIAL STATEMENTS

Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement.
Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock.
For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Commission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof.
Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts.
Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein.
For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred.
Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.

A. CASH FLOW STATEMENT, ADDITIONAL INFORMATION:


Cash and Cash Equivalents at December 31, 2024
Cash (Account 131)			$182,227
Working Fund (Account 135)			5
Temporary Cash Investments (Account 136)			151,903,633
Total			$152,085,865

Supplemental Disclosure of Cash Flow Statement
Cash paid (received) during the period for:			(in 000s)
Interest - net of amount capitalized			$108,344
Income Taxes			($14,170)

B. FERC FORM 1 PRESENTATION COMPARED TO GENERALLY ACCEPTED ACCOUNTING PRINCIPLES

The accompanying financial statements have been prepared in accordance with the accounting requirements of the FERC as set forth in the Uniform System of Accounts and accounting releases, which differs from GAAP. Additional comparative data, including the 2022 data for the statement of income, retained earnings and cash flows, are needed to present the financial position and results of operations in order to satisfy GAAP. In addition, GAAP requires the disclosure of the current and long-term portion of assets and liabilities. In accordance with FERC reporting requirements, the aforementioned disclosures were not included in these financial statements.

As required by the FERC, Entergy Mississippi classifies certain items in the income statement (primarily the classification of operating expenses and other deductions) and in the balance sheet (primarily the classification of the components of accumulated deferred income taxes, taxes accrued, certain other miscellaneous current and accrued liabilities, maturities of long-term debt, deferred debits, deferred credits, plant in service, and accumulated depreciation) in a manner different than that required by GAAP.

GAAP requires that Entergy Mississippi consolidate MS Sunflower Partnership, LLC due to the significant influence it exerts as the managing member of the partnership, whereas Entergy Mississippi's investment in the partnership is presented in the FERC Form 1 as an equity-method investment. Additionally, GAAP requires Entergy Mississippi to record the earnings it receives from the partnership using the hypothetical-liquidation at book value (HLBV) method of accounting because the limited liability agreement forming the partnership stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between Entergy Mississippi and the other investor in the partnership. In contrast, Entergy Mississippi recognizes its share in the partnership earnings based on its ownership-percentage in the partnership for reporting in the FERC Form 1.

C. The Notes to the Financial Statements included herein are adapted from the Entergy Corporation and subsidiaries Form 10-K for the Year Ended December 31, 2024. The Form 10-K Notes to the Financial Statements are prepared in conformity with GAAP, and thus may differ in certain instances from the financial statements contained herein.

"Entergy" when used in these Notes means Entergy Corporation and its direct and indirect subsidiaries.

"Registrant Subsidiaries" when used in these Notes means Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc.

"Utility" when used in the Notes means Entergy's business segment that generates, transmits, distributes, and sells electric power, with a small amount of natural gas distribution.

"Utility operating companies" when used in these Notes means Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas.

NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Use of Estimates in the Preparation of Financial Statements

In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used.

Property, Plant, and Equipment

Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens.

Details of property, plant, and equipment by functional category are presented on FERC Form 1 pages 204-207 and details of accumulated depreciation by functional category are presented on FERC Form 1 page 219.

Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
2024	2.7%	2.7%	3.5%	3.3%	3.8%	2.1%
2023	2.7%	2.6%	3.6%	3.3%	4.0%	1.6%
2022	2.7%	2.4%	3.6%	3.2%	3.1%	2.0%

Non-utility property - at cost (less accumulated depreciation) for Entergy Louisiana is reported net of accumulated depreciation of $225.4 million as of December 31, 2024 and $187.2 million as of December 31,

2023. Non-utility property - at cost (less accumulated depreciation) for Entergy Mississippi is reported net of accumulated depreciation of $0.5 million as of December 31, 2024 and $0.5 million as of December 31, 2023.

Jointly-Owned Generating Stations

Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2024, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows:


Generating Stations		Fuel Type	Total Megawatt Capability (a)	Ownership	Investment	Accumulated Depreciation
					(In Millions)
Utility:
Entergy Arkansas -
Independence	Unit 1	Coal	820	31.50%	$152	$109
Independence	Common Facilities	Coal		15.75%	$42	$32
White Bluff	Units 1 and 2	Coal	1,244	57.00%	$622	$412
Ouachita (b)	Common Facilities	Gas		66.67%	$174	$160
Union (c)	Common Facilities	Gas		25.00%	$29	$13
Entergy Louisiana -
Roy S. Nelson	Unit 6	Coal	514	40.25%	$301	$231
Roy S. Nelson	Unit 6 Common Facilities	Coal		40.25%	$22	$11
Big Cajun 2	Unit 3	Coal	551	24.15%	$149	$140
Big Cajun 2	Unit 3 Common Facilities	Coal		8.05%	$5	$3
Ouachita (b)	Common Facilities	Gas		33.33%	$91	$79
Acadia	Common Facilities	Gas		50.00%	$22	$3
Union (c)	Common Facilities	Gas		50.00%	$58	$15
Entergy Mississippi -
Independence	Units 1 and 2 and Common Facilities	Coal	1,662	25.00%	$304	$195
Entergy New Orleans -
Union (c)	Common Facilities	Gas		25.00%	$30	$11
Entergy Texas -
Roy S. Nelson	Unit 6	Coal	514	29.75%	$212	$160
Roy S. Nelson	Unit 6 Common Facilities	Coal		29.75%	$8	$4
Big Cajun 2	Unit 3	Coal	551	17.85%	$112	$115
Big Cajun 2	Unit 3 Common Facilities	Coal		5.95%	$4	$2
Montgomery County	Unit 1	Gas	915	92.44%	$759	$40
System Energy -
Grand Gulf (d)	Unit 1	Nuclear	1,390	90.00%	$5,674	$3,580
Other:
Independence	Unit 2	Coal	842	14.37%	$81	$61
Independence	Common Facilities	Coal		7.18%	$20	$16


Roy S. Nelson	Unit 6	Coal	514	10.90%	$121	$76
Roy S. Nelson	Unit 6 Common Facilities	Coal		10.90%	$3	$2

a.“Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.

b.Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units.

c.Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units.

d.Includes a leasehold interest held by System Energy. System Energy’s Grand Gulf lease obligations are discussed in Note 5 to the financial statements.

Allowance for Funds Used During Construction (AFUDC)

AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers.

Certain large industrial customers make advance payments to provide Entergy and the Utility operating companies the return on their investment in utility plant that they would otherwise have received by the recognition of AFUDC. When such advances are made, AFUDC is not added to the associated utility plant, which results in a lower amount of utility plant recovered through utility rates. These advance payments are initially recorded as a current liability and then amortized to income over the construction period of the related plant. As of December 31, 2024, Entergy and Entergy Louisiana have $152 million in such advances from customers recorded as current liabilities on their respective consolidated balance sheets.

Income Taxes

Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward.

Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “Other Tax Matters - Tax Cuts and Jobs Act” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017.

The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment.

Accounting for the Effects of Regulation

Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers.

Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement.

In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made.

Regulatory Asset or Liability for Income Taxes

Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements.

Cash and Cash Equivalents

Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents.

Allowance for Doubtful Accounts

The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements.

Materials and Supplies

Materials and supplies consist of tangible goods, equipment, and other materials that Entergy holds for use or consumption in the normal course of business, whether for capital projects or operation and maintenance activities, or that are required to be kept for regulatory reasons or service reliability. Materials and supplies are valued at a weighted average unit cost when expensed or capitalized, as appropriate, when used or installed. Materials and supplies are valued at the lower of weighted average cost or net realizable value, net of provisions for excess and obsolete materials and supplies.

Derivative Financial Instruments and Commodity Derivatives

The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries.

Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered.

Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value.

Impairment of Long-lived Assets

Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend

on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets.

Reacquired Debt

The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment.

Taxes Imposed on Revenue-Producing Transactions

Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.

NOTE 2. RATE AND REGULATORY MATTERS

Regulatory Assets and Regulatory Liabilities

Regulatory assets represent probably future revenues associated with costs that are expected to be recovered from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory liabilities represent probable future reductions in revenues associated with amounts that are expected to benefit customers through the regulatory ratemaking process under which the Utility business operates. Details of regulatory assets in FERC account 182.3 are presented on FERC Form 1 page 232. Details of regulatory liabilities in FERC account 254 are presented on FERC Form 1 page 278.

Regulatory activity regarding the Tax Cuts and Jobs Act

See the “Other Tax Matters - Tax Cuts and Jobs Act” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes.

Fuel and purchased power cost recovery

The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2024 and 2023 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review.


	2024	2023
	(In Millions)
Entergy Arkansas	($45.2)	($88.3)
Entergy Louisiana (a)	$163.4	$192.9


Entergy Mississippi	($126.3)	($130.6)
Entergy New Orleans (a)	$8.0	$10.2
Entergy Texas	($59.3)	$139.0

a.Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months.

Entergy Mississippi

Entergy Mississippi’s rate schedules include an energy cost recovery rider and a power management rider, both of which are adjusted annually to reflect accumulated over- or under-recoveries. Entergy Mississippi recovers fuel and purchased energy costs through its energy cost recovery rider and recovers costs associated with natural gas hedging and capacity payments through its power management rider. Entergy Mississippi’s fuel cost recoveries are subject to annual audits conducted pursuant to the authority of the MPSC.

In November 2021, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included an under-recovery of approximately $80.6 million as of September 30, 2021. In December 2021, at the request of the MPSC, Entergy Mississippi submitted a proposal to mitigate the impact of rising fuel costs on customer bills during 2022. Entergy Mississippi proposed that the deferred fuel balance as of December 31, 2021, which was $121.9 million, be amortized over three years and that the MPSC authorize Entergy Mississippi to apply its weighted-average cost of capital as the carrying cost for the unamortized fuel balance. In January 2022 the MPSC approved the amortization of $100 million of the deferred fuel balance over two years and authorized Entergy Mississippi to apply its weighted-average cost of capital as the carrying cost for the unamortized fuel balance. The MPSC approved the proposed energy cost factor effective for February 2022 bills.

Entergy Mississippi had a deferred fuel balance of approximately $291.7 million under the energy cost recovery rider as of July 31, 2022, along with an over-recovery balance of $51.1 million under the power management rider. Without further action, Entergy Mississippi anticipated a year-end deferred fuel balance of approximately $200 million after application of a portion of the System Energy settlement proceeds. In September 2022, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider. Entergy Mississippi proposed five monthly incremental adjustments to the net energy cost factor designed to collect the under-recovered fuel balance as of July 31, 2022 and to reflect the recovery of a higher natural gas price. Entergy Mississippi also proposed five monthly incremental adjustments to the power management adjustment factor designed to flow through to customers the over-recovered power management rider balance as of July 31, 2022. In October 2022 the MPSC approved modified interim adjustments to Entergy Mississippi’s energy cost recovery rider and power management rider. The MPSC approved dividing the energy cost recovery rider interim adjustment into two components that would allow Entergy Mississippi to (1) recover a natural gas fuel rate that is better aligned with current prices; and (2) recover the estimated under-recovered deferred fuel balance as of September 30, 2022 over a period of 20 months. The MPSC approved six monthly incremental adjustments to the net energy cost factor designed to reflect the recovery of a higher natural gas price. The MPSC also approved six monthly incremental adjustments to the power management adjustment factor designed to flow through to customers the over-recovered power management rider balance. In accordance with the order of the MPSC, Entergy Mississippi did not file an annual redetermination of the energy cost recovery rider or the power management rider in November 2022.

In June 2023 the MPSC approved the joint stipulation agreement between Entergy Mississippi and the Mississippi Public Utilities Staff for Entergy Mississippi’s 2023 formula rate plan filing. The stipulation directed Entergy Mississippi to make a compliance filing to revise its power management cost adjustment factor, to revise its grid modernization cost adjustment factor, and to include a revision to reduce the net energy cost factor to a level necessary to reflect an average natural gas price of $4.50 per MMBtu. The MPSC approved the compliance filing in June 2023, effective for July 2023 bills. See “Retail Rate Proceedings - Filings with the MPSC (Entergy Mississippi) - Retail Rates - 2023 Formula Rate Plan Filing” below for further discussion of the 2023 formula rate plan filing and the joint stipulation agreement.

In November 2023 Entergy Mississippi filed its annual redeterminations of the energy cost factor and the power management cost adjustment factor. The calculation of the annual factor for the energy cost recovery rider included a projected over-recovery balance of approximately $142 million at the end of January 2024. The calculation of the annual factor for the power management rider included a projected under-recovery of $47 million at the end of January 2024. In January 2024 the MPSC approved the proposed energy cost factor and the proposed power management cost factor effective for February 2024 bills.

In June 2024 the MPSC approved the joint stipulation agreement between Entergy Mississippi and the Mississippi Public Utilities Staff for Entergy Mississippi’s 2024 formula rate plan filing. The 2024 formula rate plan filing included the conclusion of the modified interim adjustments to Entergy Mississippi’s energy cost recovery rider and power management rider, which were approved in October 2022 and allowed Entergy Mississippi to recover certain under-collected fuel balances, effective for July 2024 bills. The stipulation provided for Entergy Mississippi to reduce its net energy cost factor. See “Retail Rate Proceedings - Filings with the MPSC (Entergy Mississippi) - Retail Rates - 2024 Formula Rate Plan Filing” below for further discussion of the 2024 formula rate plan filing and the joint stipulation agreement.

In November 2024, Entergy Mississippi filed its annual redeterminations of the energy cost factor and the power management cost adjustment factor. The calculation of the annual factor for the energy cost recovery rider included a projected over-recovery balance of approximately $144.6 million as of September 2024. The calculation of the annual factor for the power management rider included a projected under-recovery of $60.1 million as of September 2024. In January 2025 the MPSC approved a revised energy cost factor, effective for February 2025 bills, that did not reflect the fuel savings associated with Entergy Mississippi’s incremental increase in its share of capacity and energy in connection with Entergy Mississippi’s assumption of Entergy Louisiana’s entitlements to Grand Gulf capacity and energy, which was subject to the MPSC’s review at such time. In February 2025 the MPSC approved Entergy Mississippi’s notice of intent for Entergy Mississippi’s assumption of Entergy Louisiana’s entitlements to Grand Gulf capacity and energy, with associated fuel savings to be reflected in Entergy Mississippi’s energy cost recovery rider, effective for March 2025 bills. Additionally, in February 2025 the MPSC approved the proposed power management cost adjustment factor, effective for March 2025 bills.

Retail Rate Proceedings

Filings with the MPSC (Entergy Mississippi)

Retail Rates

2023 Formula Rate Plan Filing

In March 2023, Entergy Mississippi submitted its formula rate plan 2023 test year filing and 2022 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2022 calendar year to be

below the formula rate plan bandwidth and projected earned return for the 2023 calendar year to be below the formula rate plan bandwidth. The 2023 test year filing showed a $39.8 million rate increase was necessary to reset Entergy Mississippi’s earned return on rate base to the specified point of adjustment of 6.67%, within the formula rate plan bandwidth. The 2022 look-back filing compared actual 2022 results to the approved benchmark return on rate base and reflected the need for a $19.8 million temporary increase in formula rate plan revenues, including the refund of a $1.3 million over-recovery resulting from the demand-side management costs true-up for 2022. In fourth quarter 2022, Entergy Mississippi recorded a regulatory asset of $18.2 million in connection with the look-back feature of the formula rate plan to reflect that the 2022 estimated earned return was below the formula rate plan bandwidth. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $27.9 million interim rate increase, reflecting a cap equal to 2% of 2022 retail revenues, effective in April 2023.

In May 2023, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed a 2023 test year filing resulting in a total revenue increase of $26.5 million for 2023. Pursuant to the joint stipulation, Entergy Mississippi’s 2022 look-back filing reflected an earned return on rate base of 6.10% in calendar year 2022, which was below the look-back bandwidth, resulting in a $19.0 million increase in the formula rate plan revenues on an interim basis through June 2024. Entergy Mississippi recorded a regulatory credit of $0.8 million in June 2023 to reflect the increase in the look-back regulatory asset. In addition, certain long-term service agreement and conductor handling costs were authorized for realignment from the formula rate plan to the annual power management and grid modernization riders effective January 2023, resulting in regulatory credits recorded in June 2023 of $4.1 million and $4.3 million, respectively. Also, the amortization of Entergy Mississippi’s COVID-19 bad debt expense deferral was suspended for calendar year 2023, but resumed in July 2024. In June 2023 the MPSC approved the joint stipulation with rates effective in July 2023.

2024 Formula Rate Plan Filing

In March 2024, Entergy Mississippi submitted its formula rate plan 2024 test year filing and 2023 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2023 calendar year to be within the formula rate plan bandwidth and projected earned return for the 2024 calendar year to be below the formula rate plan bandwidth. The 2024 test year filing showed a $63.4 million rate increase was necessary to reset Entergy Mississippi’s earned return on rate base to the specified point of adjustment of 7.10%, within the formula rate plan bandwidth. The 2023 look-back filing compared actual 2023 results to the approved benchmark return on rate base and reflected no change in formula rate plan revenues. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $32.6 million interim rate increase, reflecting a cap equal to 2% of 2023 retail revenues, effective April 2024.

In December 2014 the MPSC ordered Entergy Mississippi to file an updated depreciation study at least once every four years. Pursuant to this order and Entergy Mississippi’s filing cycle, Entergy Mississippi would have filed an updated depreciation report with its formula rate plan filing in 2023. However, in July 2022 the MPSC directed Entergy Mississippi to file its next depreciation study in connection with its 2024 formula rate plan filing notwithstanding the MPSC’s prior order. Accordingly, Entergy Mississippi filed a depreciation study in February 2024. The study showed a need for an increase in annual depreciation expense of $55.2 million. The calculated increase in annual depreciation expense was excluded from Entergy Mississippi’s 2024 formula rate plan revenue increase request because the MPSC had not yet approved the proposed depreciation rates.

In June 2024, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2024 test year filing, with the exception of immaterial adjustments to certain operation and maintenance expenses. After performance adjustments, the formula rate plan reflected an earned return on rate

base of 6.08% for calendar year 2024, which resulted in a total revenue increase of $64.6 million for 2024. The joint stipulation also recommended approval of a revised customer charge of $31.82 per month for residential customers and $53.10 per month for general service customers. Pursuant to the stipulation, Entergy Mississippi’s 2023 look-back filing reflected an earned return on rate base of 6.81%, resulting in an increase of $0.3 million in the formula rate plan revenues for 2023. Finally, the stipulation recommended approval of Entergy Mississippi’s proposed depreciation rates with those rates to be implemented upon request and approval at a later date. In June 2024 the MPSC approved the joint stipulation with rates effective in July 2024. The approval also included a reduction to the energy cost factor, resulting in a net bill decrease for a typical residential customer using 1,000 kWh per month. Also in June 2024, Entergy Mississippi recorded regulatory credits of $7.3 million to reflect the difference between interim rates placed in effect in April 2024 and the rates reflected in the joint stipulation.

In May 2024, Entergy Mississippi received approval from the MPSC for formula rate plan revisions that were necessary for Entergy Mississippi to comply with state legislation passed in January 2024. The legislation allows Entergy Mississippi to make interim rate adjustments to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi filed the first of its annual interim facilities rate adjustment reports in May 2024 to recover approximately $8.7 million of these costs over a six-month period with rates effective beginning in July 2024. Entergy Mississippi filed its second annual interim facilities rate adjustment report in December 2024 to recover approximately $46.7 million of these costs over a 12-month period with rates effective beginning in January 2025.

Grand Gulf Capacity Filing

In September 2024, Entergy Mississippi filed a notice of intent with the MPSC to implement revisions to its unit power cost recovery rider that would allow Entergy Mississippi to recover the first year of costs associated with the transfer of Entergy Louisiana’s entitlements to Grand Gulf capacity and energy, which consists of Energy Louisiana’s interest in and purchases of Grand Gulf capacity and energy under the revised rider schedule, effective by January 1, 2025. This notice filing related to the divestiture of Entergy Louisiana’s 14% share of Grand Gulf capacity and energy under the Unit Power Sales Agreement and 2.43% share of capacity and energy from Entergy Arkansas under the MSS-4 replacement tariff. This divestiture is being effectuated initially through Entergy Mississippi’s purchases from Entergy Louisiana pursuant to a PPA governed by the MSS-4 replacement tariff, a tariff governing the sales of energy and capacity among the Utility operating companies as described in the System Energy global settlement with the LPSC and Entergy Louisiana. The MSS-4 replacement PPA to effectuate this divestiture was approved by the FERC in November 2024. In February 2025 the MPSC approved Entergy Mississippi’s notice of intent, finding that it was just and reasonable for Entergy Mississippi to obtain Entergy Louisiana’s entitlements to Grand Gulf capacity and energy and that Entergy Mississippi should be allowed to recover the costs associated with the transfer of such entitlements to Grand Gulf capacity and energy, as described above. The MPSC approved the MSS-4 replacement PPA, effective as of January 1, 2025.

Additional Generation and Transmission Resources

In January 2024, Amazon Web Services announced its plan to invest in two data centers located in Madison County, Mississippi. In March 2024, Entergy Mississippi executed a large customer supply and service agreement to serve the two data centers. Entergy Mississippi will need generation and transmission resources to reliably serve all Entergy Mississippi customers, including the data centers. The large customer supply and service agreement also contains provisions which cover Entergy Mississippi’s incremental investment costs in the event of early termination. In May 2024 the MPSC approved Entergy Mississippi’s revisions to its formula rate plan to comply with state legislation passed in January 2024 allowing Entergy Mississippi to make interim rate

adjustments, including the collection of a return on construction-work-in-process on a cash basis, to recover the non-fuel related annual ownership cost of certain facilities that directly or indirectly provide service to customers who own certain data processing center projects as specified in the legislation. Entergy Mississippi anticipates recovering the incremental cost to serve the customer through the revenues it expects to collect under the large customer supply and service agreement.

In February 2025, Entergy Mississippi entered into a new large customer supply and service agreement with a customer.

Federal Rate Proceedings

System Energy Settlement with the MPSC

In June 2022, System Energy, Entergy Mississippi, and additional named Entergy parties involved in thirteen docketed proceedings before the FERC filed with the FERC a partial settlement agreement and offer of settlement. The settlement memorialized the Entergy parties’ agreement with the MPSC to globally resolve all actual and potential claims between the Entergy parties and the MPSC associated with those FERC proceedings and with System Energy’s past implementation of the Unit Power Sales Agreement. The Unit Power Sales Agreement is a FERC-jurisdictional formula rate tariff for sales of energy and capacity from System Energy’s owned and leased share of Grand Gulf to Entergy Mississippi, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans. Entergy Mississippi purchases the greatest single amount, nearly 40% of System Energy’s share of Grand Gulf, after its additional purchases from affiliates are considered.

The settlement provided for a black box refund of $235 million from System Energy to Entergy Mississippi. In addition, beginning with the July 2022 service month, the settlement provided for Entergy Mississippi’s bills from System Energy to be adjusted to reflect: an authorized rate of return on equity of 9.65%, a capital structure not to exceed 52% equity, a rate base reduction for the advance collection of sale-leaseback rental costs, and the exclusion of certain long-term incentive plan performance unit costs from rates. The settlement was approved by the MPSC in June 2022 and the FERC in November 2022.

System Energy paid the black box refund of $235 million to Entergy Mississippi in November 2022.

Storm Cost Recovery Filings with Retail Regulators

Entergy Mississippi

Prior to June 2024, Entergy Mississippi had approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeded $15 million, the collection of the storm damage provision ceased until such time that the accumulated storm damage provision became less than $10 million. Entergy Mississippi’s storm damage provision balance had been less than $10 million since May 2019, and Entergy Mississippi had been billing the monthly storm damage provision since July 2019.

In December 2023, Entergy Mississippi filed a Notice of Storm Escrow Disbursement and Request for Interim Relief notifying the MPSC that Entergy Mississippi had requested disbursement of approximately $34.5 million of storm escrow funds from its restricted storm escrow account. The filing also requested authorization from the MPSC, on a temporary basis, that the $34.5 million of storm escrow funds be credited to Entergy Mississippi’s storm damage provision, pending the MPSC’s review of Entergy Mississippi’s storm-related costs, and that Entergy Mississippi continue to bill its monthly storm damage provision without suspension in the event

the storm damage provision balance exceeded $15 million, in anticipation of a subsequent filing by Entergy Mississippi in this proceeding. The storm damage provision exceeded $15 million upon receipt of the storm escrow funds. Because the MPSC had not entered an order on Entergy Mississippi’s filing on the requested relief to continue billing this provision, Entergy Mississippi suspended billing the monthly storm damage provision effective with February 2024 bills.

In March 2024, Entergy Mississippi made a combined dual filing which included a notice of intent to make routine change in rates and schedules and a motion for determination relating to the above-described notice of storm escrow disbursement. The notice of intent proposed a new storm damage mitigation and restoration rider to supersede both the then-current storm damage rate schedule and the vegetation management rider schedule, in which the collection of both expenses would be combined. The proposal requested that the MPSC authorize Entergy Mississippi to collect approximately $5.2 million per month for vegetation management and a storm damage provision. Furthermore, if Entergy Mississippi’s accumulated vegetation management and storm damage provision balance were to exceed $70 million, collection under the storm damage mitigation and restoration rider would cease until such time that the accumulated vegetation management and storm damage provision would become less than $60 million.

The Mississippi Public Utilities Staff reviewed the storm-related costs submitted by Entergy Mississippi and found them prudent. In June 2024 the MPSC considered and unanimously granted the relief sought by Entergy Mississippi, including authorization to credit any remaining funds in the storm escrow account to Entergy Mississippi’s storm damage provision and to close the storm escrow account and approving the new storm damage mitigation and restoration rider. Entergy Mississippi’s storm escrow account was liquidated in July 2024, and the new combined storm damage mitigation and restoration rider became effective with the July 2024 billing cycle. Additionally, Entergy Mississippi made a compliance filing to cease billing under the existing vegetation management rider schedule as of the same billing cycle.

NOTE 3. INCOME TAXES

Details regarding income taxes are presented on FERC Form 1 pages 261-267 and 272-277.

The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2024 are as follows:

Entergy Arkansas

Entergy Louisiana

Entergy Mississippi

Entergy New Orleans

Entergy Texas

System Energy

Federal net operating losses before 1/1/2018

$— million

$812.8 million

$— million

$82.6 million

$— million

Year(s) of expiration

N/A

2035-2037

N/A

2037

N/A

Federal net operating losses - 1/1/2018 forward

$576 million

$2.6 billion

$— million

$26.4 million

$1.5 billion

$264.7 million

Year(s) of expiration

N/A

State net operating losses

$597.4 million

$5.8 billion

$7.1 million

$336.6 million

$1 million

$370.1 million

Year(s) of expiration

2028-2032

N/A

2039-2042

N/A

2028

2040-2044

Misc. federal credits

$12.9 million

$21 million

$4.9 million

$16.7 million

$0.8 million

$5.7 million

Year(s) of expiration

2038-2044

2035-2044

2038-2044

2037-2044

2039-2044

2029-2044

State credits

$— million

$1.1 million

$8.3 million

$— million

$1.3 million

$17 million

Year(s) of expiration

N/A

2025-2028

N/A

2027-2033

2025-2028

Unrecognized tax benefits

Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded.

A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2024, 2023, and 2022 is as follows:


2024	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Gross balance at January 1, 2024	$69,197	$864,043	$5,653	$19,331	$415,205	$14,301
Additions based on tax positions related to the current year	2,732	1,921	237	163	378	833
Additions for tax positions of prior years	25,784	10,357	536	153	560	1,281
Reductions for tax positions of prior years	(52,300)	(9,205)	(437)	(139)	(31,810)	—
Gross balance at December 31, 2024	45,413	867,116	5,989	19,508	384,333	16,415
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers	(30,333)	(753,101)	(4,997)	(11,639)	(314,446)	(16,415)
Unrecognized tax benefits net of unused tax attributes	$15,080	$114,015	$992	$7,869	$69,887	$—


2023	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Gross balance at January 1, 2023	$1,452,819	$1,350,836	$547,548	$638,726	$389,366	$23,702
Additions based on tax positions related to the current year	2,249	332,320	209	78	196	752
Additions for tax positions of prior years	—	—	—	—	94,793	—
Reductions for tax positions of prior years (a)	(148,558)	(458,072)	(16,853)	(191,336)	(67,156)	(9,532)
Settlements (a)	(1,237,313)	(361,041)	(525,251)	(428,137)	(1,994)	(621)
Gross balance at December 31, 2023	69,197	864,043	5,653	19,331	415,205	14,301
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers	(34,683)	(735,612)	(3,778)	(11,721)	(381,561)	(14,301)
Unrecognized tax benefits net of unused tax attributes	$34,514	$128,431	$1,875	$7,610	$33,644	$—


2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Gross balance at January 1, 2022	$1,408,494	$604,628	$549,569	$639,497	$552,295	$23,356
Additions based on tax positions related to the current year	40,502	750,320	185	72	173	690
Additions for tax positions of prior years	6,233	10,262	1,122	393	801	761
Reductions for tax positions of prior years	(2,410)	(14,374)	(3,328)	(1,236)	(163,903)	(1,105)
Gross balance at December 31, 2022	1,452,819	1,350,836	547,548	638,726	389,366	23,702
Offsets to gross unrecognized tax benefits:
Loss and tax credit carryovers	(1,277,414)	(1,328,916)	(504,940)	(455,928)	(377,054)	(23,702)
Unrecognized tax benefits net of unused tax attributes	$175,405	$21,920	$42,608	$182,798	$12,312	$—

a.Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “Income Tax Audits - 2016-2018 IRS Audit” below.

The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows:


	December 31,
	2024	2023	2022
	(In Millions)
Entergy Arkansas	$32.6	$57.2	$377.9
Entergy Louisiana	$868.2	$862.5	$720.8
Entergy Mississippi	$1.3	$1.0	$151.2
Entergy New Orleans	$18.3	$18.2	$310.7
Entergy Texas	$50.3	$2.9	$3.3
System Energy	$4.0	$3.1	$2.5

Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows:


	December 31,
	2024	2023	2022
	(In Millions)
Entergy Arkansas	$8.4	$7.8	$4.3
Entergy Louisiana	$5.1	$1.5	$4.1
Entergy Mississippi	$3.2	$2.1	$3.1
Entergy New Orleans	$0.6	$0.6	$6.4
Entergy Texas	$0.5	$—	$1.1
System Energy	$2.9	$1.9	$1.9

The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2024, 2023, and 2022. Interest (net-of-tax) was recorded as follows:


	2024	2023	2022
	(In Millions)
Entergy Arkansas	$0.6	$3.5	$1.6
Entergy Louisiana	$3.6	($2.6)	$0.4
Entergy Mississippi	$1.1	($1.0)	$0.7
Entergy New Orleans	$—	($5.8)	$1.2
Entergy Texas	$0.5	($1.1)	$—
System Energy	$1.0	$—	($10.2)

Income Tax Audits

Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2019. All state taxing authorities’ examinations are complete for years before 2016. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months.

2016-2018 IRS Audit

The IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report (RAR) for each federal filer under audit in November 2023. Entergy agreed to all adjustments contained in the RARs. Entergy and the Registrant Subsidiaries recorded all the material effects resulting from the RARs in the fourth quarter of 2023.

Utility Restructurings

In 2017, Entergy New Orleans undertook an internal restructuring, and in 2018, Entergy Arkansas and Entergy Mississippi also participated in internal restructurings under which these three Utility operating companies joined Entergy Louisiana as wholly-owned subsidiaries of Entergy Utility Holding Company, LLC. The change in ownership required Entergy to recognize Entergy Arkansas’s nuclear decommissioning liabilities for income tax purposes, which resulted in recognition of a gain for income tax purposes and a corresponding increase in the tax basis of assets, in accordance with the Internal Revenue Code and Treasury Regulations. Entergy determined that there was uncertainty regarding the treatment of certain aspects of the restructurings and recorded provisions for uncertain tax positions which are now considered to be effectively settled in accordance with accounting standards. The reversal of such provisions for uncertain tax positions results in a reduction of income tax expense of $156 million for Entergy Arkansas, $1 million for Entergy Mississippi, and $6 million for Entergy New Orleans.

Mark-to-Market Method of Accounting

In 2018, Entergy Arkansas and Entergy Mississippi each accrued approximately $2 billion in deductible temporary differences related to mark-to-market tax accounting for the Unit Power Sales Agreement and various wholesale electric contracts. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The effective

settlement of the mark-to-market tax position for Entergy Arkansas resulted in the accrual of an increase to tax expense of $40 million, which was offset by approximately $5 million of miscellaneous excess ADIT recognized as a result of the 2016-2018 IRS audit resolution. The net increase to tax expense is deferred as a regulatory asset, as discussed within the “Regulatory and Other Matters” section below.

Reduction of Net Operating Loss Carryovers

The IRS audit reduced Entergy’s net operating loss carryover by $8 billion. A portion of Entergy’s audit adjustments were not offset by losses which resulted in a tax liability of $79 million, which was fully offset by prior deposits made by Entergy. Entergy received an assessment of interest in excess of prior deposits of $13 million in December 2023, and such interest was paid in January 2024.

Net operating loss carryovers were reduced by $4 billion for Entergy Arkansas, $1 billion for Entergy Louisiana, $2 billion for Entergy Mississippi, $1 billion for Entergy New Orleans, and $40 million for System Energy. The IRS audit adjustments were also factored into the settle-up required under Entergy’s intercompany income tax allocation agreement, and such amounts were settled in the fourth quarter of 2023.

Regulatory and Other Matters

In December 2023, a regulatory asset for income tax associated with deficient ADIT of $35 million, $2 million, and $3 million, was recorded for Entergy Arkansas, Entergy Louisiana, and Entergy Mississippi, respectively. See Note 2 to the financial statements for discussion of Entergy Arkansas’s regulatory activity related to the Tax Cuts and Jobs Act and discussion of the settlement of Entergy Arkansas’s 2023 formula rate plan.

Entergy accrues interest expense related to unrecognized tax benefits in income tax expense. As a result of the IRS audit resolution, Entergy reversed approximately $24 million of interest related to the allowance of previously unrecognized tax benefits in December 2023.

Reversal of net deferred credits associated with the accounting for income taxes upon the resolution of the IRS audit resulted in a reduction/(increase) in income tax expense in December 2023 of $9 million, $42 million, ($2) million, $2 million, $2 million, and $1 million for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy, respectively.

Included in the effect of the IRS audit on the results of operations was the measurement of deferred tax assets and liabilities influenced by the 2017 enactment of the Tax Cuts and Jobs Act income tax rate change discussed below. With the conclusion of the audit, there are no remaining federal unrecognized tax benefits affected by the rate differential which could impact income tax expense and the regulatory liability for income taxes in future periods.

Other Tax Matters

Tax Cuts and Jobs Act (TCJA)

The most significant effect of the TCJA for Entergy and the Registrant Subsidiaries was the change in the federal corporate income tax rate from 35% to 21%, effective January 1, 2018. Entergy had regulatory liability balances of $1.2 billion and $1.0 billion as of December 31, 2024 and December 31, 2023, respectively. These liabilities were primarily associated with the re-measurement of deferred tax assets and liabilities due to the income tax rate change, subsequent amortization of excess ADIT, and payments to customers since the enactment

of the TCJA. In addition to the protected and unprotected excess ADIT amounts, the net regulatory liability for income taxes includes other regulatory assets and liabilities for income taxes mainly related to AFUDC, as described in Note 1 to the financial statements.

Entergy’s regulatory liability for income taxes includes a gross-up at the applicable tax rate to account for the effect of excess ADIT on the ratemaking formula. The regulatory liability for income taxes reflects (1) the reduction of the net deferred tax liability resulting in excess ADIT, and (2) the tax gross-up of excess ADIT. The Registrant Subsidiaries’ December 31, 2024 and December 31, 2023 balance sheets reflect net regulatory liabilities for income taxes as follows:


	2024	2023
	(In Millions)
Entergy Arkansas	$418	$392
Entergy Louisiana	$355	$194
Entergy Mississippi	$181	$189
Entergy New Orleans	$15	$36
Entergy Texas	$94	$115
System Energy	$105	$107

Excess ADIT is generally classified into two categories: (1) the portion that is subject to the normalization requirements of the TCJA, referred to as “protected”, and (2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. See Note 2 to the financial statements for discussion of Entergy Louisiana’s $106 million reversal of a regulatory liability, primarily associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the TCJA, recorded in fourth quarter 2023.

The majority of the remaining unamortized Excess ADIT as of December 31, 2024 is classified as protected. The TCJA mandates the normalization method of accounting for income taxes for excess ADIT associated with public utility property. The TCJA specifies the use of the average rate assumption method (ARAM) to determine of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in compliance with the normalization requirements.

During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the TCJA, to their customers through rate riders and other mechanisms approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. The return of unprotected excess accumulated deferred income taxes was substantially completed by Entergy and the Registrant Subsidiaries during 2022.

Tax Accounting Methods

Certain Entergy subsidiaries have elected to apply the mark-to-market method of accounting for income tax return purposes to wholesale power purchase agreements as appropriate under the Internal Revenue Code and U.S. Treasury Regulations. The mark-to-market tax gain or loss computed each year is based on an estimated fair market valuation which includes analyses of market prices and conditions.

NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2024 as follows:


Company	Expiration Date	Amount of Facility	Interest Rate (a)	Amount Drawn as of December 31, 2024	Letters of Credit Outstanding as of December 31, 2024
Entergy Arkansas	April 2026	$25 million (b)	6.31%	—	—
Entergy Arkansas	June 2029	$300 million (c)	5.58%	—	—
Entergy Louisiana	June 2029	$400 million (c)	5.71%	—	—
Entergy Mississippi	June 2029	$300 million (c)	5.58%	—	—
Entergy New Orleans	June 2027	$25 million (c)	6.08%	—	—
Entergy Texas	June 2029	$300 million (c)	5.71%	—	$1.1 million

a.The interest rate is the estimated interest rate as of December 31, 2024 that would have been applied to outstanding borrowings under the facility.

b.Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option.

c.The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $5 million for Entergy Mississippi; $10 million for Entergy New Orleans; and $25 million for Entergy Texas.

The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant.

In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2024:

Company

Amount of Uncommitted Facility

Letter of Credit Fee

Letters of Credit Issued as of

December 31, 2024

(a) (b)

Entergy Arkansas

$25 million

0.78%

$18.1 million

Entergy Louisiana

$125 million

0.78%

$46.2 million

Entergy Mississippi

$65 million

0.78%

$33.1 million

Entergy New Orleans

$1 million

1.625%

$0.5 million

Entergy Texas

$150 million

1.250%

$93.4 million

a.As of December 31, 2024, letters of credit posted with MISO covered financial transmission rights exposure of $0.5 million for Entergy Arkansas, $0.1 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $0.1 million for Entergy New Orleans, and $0.3 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights.

b.As of December 31, 2024, the letters of credit issued for Entergy Mississippi include $31.8 million in MISO letters of credit and $1.3 million in non-MISO letters of credit outstanding under this facility.

The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have FERC-authorized short-term borrowing limits effective through January 2027. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements. The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2024 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:


	Authorized	Borrowings
	(In Millions)
Entergy Arkansas	$250	$15
Entergy Louisiana	$450	$—
Entergy Mississippi	$200	$—
Entergy New Orleans	$150	$—
Entergy Texas	$200	$—
System Energy	$200	$—

NOTE 5. LONG - TERM DEBT

Details of long-term debt are presented on FERC Form 1 pages 256-257. Entergy Mississippi has obtained long-term financing authorization from the FERC that extends through January 2027.

NOTE 6. PREFERRED EQUITY AND NONCONTROLLING INTERESTS

Note 6 to the financial statements is not applicable to Entergy Mississippi.

NOTE 7. COMMON EQUITY

Note 7 to the financial statements is not applicable to Entergy Mississippi.

NOTE 8. COMMITMENTS AND CONTINGENCIES

Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements.

Non-Nuclear Property Insurance

Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge.

Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property.

Employment and Labor-related Proceedings

The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored employee benefit plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Registrant Subsidiaries.

Grand Gulf-Related Agreements

Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

System Energy sells all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas - 36%, Entergy Louisiana - 14%, Entergy Mississippi - 33%, and Entergy New Orleans - 17%) as ordered by the FERC under the Unit Power Sales Agreement. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. Grand Gulf’s operating license currently extends through 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2024 under the agreement were approximately $16.8 million for Entergy Arkansas, $7.0 million for Entergy Louisiana, $16.4 million for Entergy Mississippi, and $8.4 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of proceedings regarding the Unit Power Sales Agreement.

In August 2024 the LPSC approved a settlement with Entergy Louisiana to globally resolve all of the LPSC’s actual and potential claims in multiple docketed proceedings pending before the FERC and with System Energy’s past implementation of the Unit Power Sales Agreement. The settlement was approved by the FERC in November 2024. The terms of the settlement included an agreement that Entergy Louisiana would divest to Entergy Mississippi its 14% share of capacity and energy from Grand Gulf under the Unit Power Sales Agreement and its 2.43% share of capacity and energy from Entergy Arkansas under the MSS-4 replacement tariff. This divestiture is being effectuated initially through Entergy Mississippi’s purchases from Entergy Louisiana pursuant to a PPA governed by the MSS-4 replacement tariff. In September 2024, Entergy Mississippi filed a notice of intent with the MPSC that related to and sought approval of the divestiture. The MSS-4 replacement PPA to effectuate this divestiture was approved by the FERC in November 2024. The MPSC approved the MSS-4 replacement PPA, effective as of January 1, 2025. Under the divestiture, Entergy Mississippi also assumes any and all of Entergy Louisiana’s rights and obligations under the Availability Agreement and will hold Entergy Louisiana harmless with respect thereto, as of January 1, 2025.

Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas - 17.1%, Entergy Louisiana - 26.9%, Entergy Mississippi - 31.3%, and Entergy New Orleans - 24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain of its debt obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement to System Energy have exceeded the amounts payable under the Availability Agreement and, therefore, no payments under the Availability Agreement have ever been required. However, if Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or certain of its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments because their allocated shares under the Availability Agreement exceed their allocated shares under the Unit Power Sales Agreement. Under the Entergy Louisiana divestiture described in “Unit Power Sales Agreement” above, Entergy Mississippi assumed any and all of Entergy Louisiana’s rights and obligations under the Availability Agreement and will hold Entergy Louisiana harmless with respect thereto, effective as of January 1, 2025.

Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy)

System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. The FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. Effective December 2024, the parties terminated the Reallocation Agreement.

NOTE 9. ASSET RETIREMENT OBLIGATIONS

Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. The remainder of removal costs included in the decommissioning and asset retirement costs line item on the balance sheets is associated with non-nuclear power plants.

These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries.

The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2024 and 2023 for the Registrant Subsidiaries were as follows:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy

Liabilities as of December 31, 2022	$1,472.7	$1,736.8	$7.8	$—	$11.1	$1,042.5
Accretion	87.4	88.6	0.4	0.5	0.6	41.7
Change in cash flow estimate	—	10.8	—	4.1	—	—
Liabilities as of December 31, 2023	1,560.1	1,836.2	8.2	4.6	11.7	1,084.2
Liabilities incurred (a)	17.7	19.4	4.0	—	—	—
Accretion	93.6	94.4	1.1	0.3	0.8	43.5
Change in cash flow estimate	20.2	(107.1)	11.8	—	5.2	—
Liabilities as of December 31, 2024	$1,691.6	$1,842.9	$25.1	$4.9	$17.7	$1,127.7

a.See “Other” below for additional discussion regarding the asset retirement obligations established at Entergy Arkansas, Entergy Louisiana, and Entergy Mississippi.

Coal Combustion Residuals

In April 2015 the EPA published the final coal combustion residuals (CCR) rule regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes regulated under Resource Conservation and Recovery Act Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria, but excluded CCRs that are beneficially reused in certain processes. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed.

In second quarter 2024, revisions were recorded to the estimated decommissioning cost liabilities for White Bluff and Independence as a result of the EPA rule that was finalized in May 2024 establishing management standards for legacy CCR surface impoundments (i.e., inactive surface impoundments at inactive power plants) and establishing a new class of units referred to as CCR management units (CCRMUs) (i.e., non-containerized CCR located at a regulated CCR facility). Entergy does not have any legacy impoundments; however, the definition of CCR management units includes on-site areas where CCR was beneficially used. This is contrary to the previous CCR rule which exempted beneficial uses that met certain criteria. Under this expanded rule, all facilities must identify and delineate any CCRMU greater than one ton and submit a facility evaluation report by February 2026. Any potential requirements for corrective action or operational changes under the various CCR rules continue to be assessed. Given the complexity and recency of the EPA guidance, Entergy is still evaluating the level of work that will ultimately be required to comply with the rule. Based on initial estimates of multiple possible remediation scenarios, Entergy Arkansas and Entergy Mississippi recorded increases of $31.2 million and $9.1 million, respectively, in their decommissioning cost liabilities, along with corresponding increases in the related asset retirement cost assets that will be depreciated over the remaining useful lives of the units. Entergy will continue to update the asset retirement obligation as the requirements of the revised CCR rule are clarified.

NOTE 10. LEASES

As of December 31, 2024 and 2023, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease.

Leases have remaining terms of one year to 56 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly.

The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2024:

Entergy Arkansas

Entergy Louisiana

Entergy Mississippi

Entergy

New Orleans

Entergy Texas


	(In Thousands)
Operating lease cost	$19,382	$19,770	$9,482	$2,234	$7,977
Finance lease cost:
Amortization of right-of-use assets	$4,675	$5,755	$2,604	$1,240	$2,104
Interest on lease liabilities	$990	$1,068	$1,116	$264	$399

Of the lease costs disclosed above, Entergy Mississippi had $0.5 million in short-term lease costs for the year ended December 31, 2024.

The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Operating lease cost	$17,065	$16,906	$7,837	$1,912	$7,290
Finance lease cost:
Amortization of right-of-use assets	$3,633	$4,835	$2,227	$1,025	$1,786
Interest on lease liabilities	$545	$729	$973	$150	$284

Of the lease costs disclosed above, Entergy Mississippi had $1.1 million in short-term lease costs for the year ended December 31, 2023.

The lease costs for the years ended December 31, 2024 and 2023 disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities.

Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below.

Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2024 and 2023 are the following amounts:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2024
Operating leases	$64,960	$65,909	$32,399	$7,971	$27,524
Finance leases	$36,105	$26,159	$22,641	$6,451	$10,822

2023


Operating leases	$61,718	$54,047	$25,470	$6,119	$21,321
Finance leases	$17,622	$21,438	$22,661	$4,779	$8,714

The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2024:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Current liabilities :
Operating leases	$17,159	$17,016	$8,116	$1,885	$7,387
Finance leases	$3,734	$5,620	$3,228	$1,218	$2,185
Non-current liabilities :
Operating leases	$47,799	$48,896	$24,294	$5,995	$20,142
Finance leases	$32,584	$20,539	$20,271	$5,233	$8,637

The following lease-related liabilities are recorded within the respective Other lines on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Current liabilities:
Operating leases	$15,514	$14,771	$6,754	$1,681	$6,023
Finance leases	$3,743	$4,870	$3,059	$991	$1,865
Non-current liabilities:
Operating leases	$46,211	$39,282	$18,722	$4,377	$15,304
Finance leases	$13,879	$16,568	$19,602	$3,788	$6,849

The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2024:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
Weighted-average remaining lease terms:
Operating leases	4.39	4.64	5.25	6.08	4.59
Finance leases	11.32	5.60	17.58	5.91	5.74
Weighted-average discount rate:


Operating leases	4.38%	4.38%	4.52%	4.40%	4.55%
Finance leases	4.38%	4.28%	5.18%	4.19%	4.19%

The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
Weighted-average remaining lease terms:
Operating leases	4.62	4.60	5.34	6.38	4.44
Finance leases	5.57	5.40	17.82	5.73	5.49
Weighted-average discount rate:
Operating leases	4.04%	4.01%	4.08%	4.02%	4.43%
Finance leases	3.77%	3.85%	5.08%	3.69%	3.76%

Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2024 are as follows:

Operating Leases


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2025	$19,625	$20,093	$9,764	$2,194	$8,679
2026	17,923	17,733	8,540	1,859	7,577
2027	15,301	15,425	7,744	1,539	5,903
2028	9,588	11,561	5,952	1,265	4,546
2029	4,915	6,328	3,212	862	2,891
Years thereafter	4,543	4,473	3,126	1,395	1,908
Minimum lease payments	71,895	75,613	38,338	9,114	31,504
Less: amount representing interest	6,937	9,701	5,928	1,234	3,975
Present value of net minimum lease payments	$64,958	$65,912	$32,410	$7,880	$27,529

Finance Leases


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2025	$6,455	$6,723	$3,640	$1,469	$2,628
2026	6,084	5,974	3,331	1,399	2,421
2027	5,444	5,084	2,877	1,263	2,096


2028	4,606	4,183	2,444	1,057	1,808
2029	3,793	3,303	2,001	864	1,356
Years thereafter	23,226	4,516	24,082	1,252	1,936
Minimum lease payments	49,608	29,783	38,375	7,304	12,245
Less: amount representing interest	13,290	3,624	14,876	853	1,423
Present value of net minimum lease payments	$36,318	$26,159	$23,499	$6,451	$10,822

In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations and to allocate the contract consideration to both lease and non-lease components for real estate leases.

NOTE 11. RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS

Qualified Pension Plans

Entergy has defined benefit qualified pension plans, including the Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees (Bargaining Plan II), the Entergy Corporation Retirement Plan III (Plan III), the Entergy Corporation Retirement Plan IV for Bargaining Employees, Entergy Corporation Retirement Plan VI for Non-Bargaining Employees (Non-Bargaining Plan VI), and the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). The Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan) was merged with and into Non-Bargaining Plan I effective January 1, 2022. Effective January 1, 2024, Non-Bargaining Plan I was amended to spin-off predominately inactive participants into a new qualified pension plan, Non-Bargaining Plan VI. Effective January 1, 2025, Bargaining Plan I was amended to spin-off predominately inactive participants into a new qualified pension plan, Entergy Corporation Plan VI for Bargaining Employees (Bargaining Plan VI). The Bargaining Cash Balance Plan was merged with and into Bargaining Plan I also effective January 1, 2025.

The Registrant Subsidiaries participate in these plans: Non-Bargaining Plan I, Bargaining Plan I, Plan III, Non-Bargaining Plan VI, and Bargaining Cash Balance Plan.

Non-bargaining and bargaining employees whose most recent date of hire was prior to June 30, 2014 (or such later date provided for in their applicable collective bargaining agreement) participate in a noncontributory final average pay formula that provides pension benefits based on the employee’s credited service and compensation during employment. Non-bargaining and bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 (or such later date provided for in their applicable collective bargaining agreement) do not participate in a final average pay formula, but instead participate in a cash balance formula. Effective January 1, 2021, the Non-Bargaining Cash Balance Plan and Bargaining Cash Balance Plan were amended to close participation in each plan to those employees whose most recent hire date is after December 31, 2020 (or such later date provided for in their applicable collective bargaining agreement). Employees hired after this date instead may be eligible to participate in and receive a discretionary employer contribution under an Entergy sponsored tax-qualified defined contribution plan that includes a 401(k) feature.

The assets of the defined benefit qualified pension plans are held in a master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in the master trust that is maintained by a trustee. Use of the master trust permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trust are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in the trust to the various participating pension plans in the trust. The fair value of the trust’s assets is determined by the trustee and certain investment managers. The trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trust on a pro rata basis.

Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions and are decreased for benefit payments. A plan’s investment net income/loss (i.e., interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter.

Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions.

Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI)

The Registrant Subsidiaries’ total 2024, 2023, and 2022 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components:


2024	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period	$16,398	$22,204	$5,135	$1,760	$3,846	$5,525
Interest cost on projected benefit obligation	52,870	55,843	14,084	6,276	11,324	13,525
Expected return on assets	(72,620)	(77,786)	(20,451)	(8,814)	(16,308)	(18,485)
Recognized net loss	22,983	10,407	4,562	1,881	1,574	4,638
Settlement charges	—	—	—	—	—	615
Net pension cost	$19,631	$10,668	$3,330	$1,103	$436	$5,818
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)


Arising this period:
Net gain	($49,352)	($55,010)	($10,857)	($8,990)	($6,190)	($9,812)
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss	(22,983)	(10,407)	(4,562)	(1,881)	(1,574)	(4,638)
Settlement charges	—	—	—	—	—	(615)
Total	($72,335)	($65,417)	($15,419)	($10,871)	($7,764)	($15,065)
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)	($52,704)	($54,749)	($12,089)	($9,768)	($7,328)	($9,247)


2023	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period	$18,461	$24,716	$5,775	$1,955	$4,328	$5,749
Interest cost on projected benefit obligation	56,026	60,346	15,402	6,747	12,726	13,852
Expected return on assets	(70,574)	(75,757)	(19,423)	(8,798)	(16,641)	(17,585)
Recognized net loss	19,400	19,797	5,719	1,694	4,075	4,236
Settlement charges	26,137	40,437	12,242	2,080	11,230	6,375
Net pension cost	$49,450	$69,539	$19,715	$3,678	$15,718	$12,627
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net gain	($30,674)	($71,016)	($20,220)	($3,183)	($16,759)	($3,268)
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss	(19,400)	(19,797)	(5,719)	(1,694)	(4,075)	(4,236)
Settlement charges	(26,137)	(40,437)	(12,242)	(2,080)	(11,230)	(6,375)
Total	($76,211)	($131,250)	($38,181)	($6,957)	($32,064)	($13,879)
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)	($26,761)	($61,711)	($18,466)	($3,279)	($16,346)	($1,252)


2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Net periodic pension cost:
Service cost - benefits earned during the period	$25,210	$33,520	$8,043	$2,745	$5,999	$7,746


Interest cost on projected benefit obligation	45,378	49,330	12,979	5,491	10,729	11,286
Expected return on assets	(75,820)	(82,478)	(20,168)	(9,920)	(18,317)	(18,173)
Recognized net loss	43,597	41,711	12,594	4,787	9,013	10,938
Settlement charges	36,409	58,550	15,786	6,676	22,411	9,905
Net pension cost	$74,774	$100,633	$29,234	$9,779	$29,835	$21,702
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net (gain) loss	$28,365	($15,604)	($4,743)	$525	$13,363	($7,063)
Amounts reclassified from regulatory asset and/or AOCI to net periodic pension cost in the current year:
Amortization of net loss	(43,597)	(41,711)	(12,594)	(4,787)	(9,013)	(10,938)
Settlement charges	(36,409)	(58,550)	(15,786)	(6,676)	(22,411)	(9,905)
Total	($51,641)	($115,865)	($33,123)	($10,938)	($18,061)	($27,906)
Total recognized as net periodic pension cost, regulatory asset, and/or AOCI (before tax)	$23,133	($15,232)	($3,889)	($1,159)	$11,774	($6,204)

Qualified Pension Obligations, Plan Assets, Funded Status, and Amounts Recognized in the Balance Sheet

Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2024 and 2023 are as follows:


2024	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Change in Projected Benefit Obligation (PBO)
Balance at January 1	$1,117,585	$1,173,283	$295,942	$133,950	$239,984	$286,558
Service cost	16,398	22,204	5,135	1,760	3,846	5,525
Interest cost	52,870	55,843	14,084	6,276	11,324	13,525
Actuarial gain	(48,020)	(46,895)	(10,071)	(6,098)	(6,102)	(8,908)
Benefits paid (a)	(77,770)	(81,411)	(22,019)	(8,755)	(19,110)	(21,583)
Balance at December 31	$1,061,063	$1,123,024	$283,071	$127,133	$229,942	$275,117
Change in Plan Assets
Fair value of assets at January 1	$991,894	$1,058,711	$280,260	$117,923	$222,496	$255,443
Actual return on plan assets	73,952	85,900	21,237	11,706	16,395	19,389
Employer contributions	55,112	48,401	14,980	4,931	8,272	16,650
Benefits paid (a)	(77,770)	(81,411)	(22,019)	(8,755)	(19,110)	(21,583)
Fair value of assets at December 31	$1,043,188	$1,111,601	$294,458	$125,805	$228,053	$269,899
Funded status	($17,875)	($11,423)	$11,387	($1,328)	($1,889)	($5,218)


Amounts recognized in the balance sheet (funded status)
Non-current assets	$29,521	$10,010	$19,666	$3,299	$6,064	$3,135
Non-current liabilities	(47,396)	(21,433)	(8,279)	(4,627)	(7,953)	(8,353)
Total funded status	($17,875)	($11,423)	$11,387	($1,328)	($1,889)	($5,218)
Amounts recognized as regulatory asset
Net loss	$412,777	$256,316	$86,790	$34,039	$55,902	$96,932
Amounts recognized as AOCI (before tax)
Net loss	$—	$10,680	$—	$—	$—	$—

a.Including settlement lump sum benefit payments of ($2.1) million at System Energy.


2023	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Change in Projected Benefit Obligation (PBO)
Balance at January 1	$1,168,098	$1,256,422	$320,994	$140,436	$265,565	$288,302
Service cost	18,461	24,716	5,775	1,955	4,328	5,749
Interest cost	56,026	60,346	15,402	6,747	12,726	13,852
Actuarial (gain) loss	39,643	1,925	(328)	4,590	(1,416)	14,522
Benefits paid (a)	(164,643)	(170,126)	(45,901)	(19,778)	(41,219)	(35,867)
Balance at December 31	$1,117,585	$1,173,283	$295,942	$133,950	$239,984	$286,558
Change in Plan Assets
Fair value of assets at January 1	$961,178	$1,035,574	$265,736	$119,710	$226,417	$240,392
Actual return on plan assets	140,891	148,698	39,315	16,571	31,984	35,375
Employer contributions	54,468	44,565	21,110	1,420	5,314	15,543
Benefits paid (a)	(164,643)	(170,126)	(45,901)	(19,778)	(41,219)	(35,867)
Fair value of assets at December 31	$991,894	$1,058,711	$280,260	$117,923	$222,496	$255,443
Funded status	($125,691)	($114,572)	($15,682)	($16,027)	($17,488)	($31,115)
Amounts recognized in the balance sheet (funded status)
Non-current liabilities	($125,691)	($114,572)	($15,682)	($16,027)	($17,488)	($31,115)
Amounts recognized as regulatory asset
Net loss	$485,113	$319,116	$102,208	$44,911	$63,665	$111,996
Amounts recognized as AOCI (before tax)
Net loss	$—	$13,296	$—	$—	$—	$—

a.Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy.

The qualified pension plans incurred net actuarial gains during 2024 primarily due to liability gains due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations; partially offset by asset losses resulting from an actual return on assets lower than the expected return on assets in some plans. The qualified pension plans incurred net actuarial gains during 2023 primarily due to asset gains resulting from an actual return on assets much higher than the expected return on assets, offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations.

The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2024 and 2023 was as follows:


	2024	2023
	(In Thousands)
Entergy Arkansas	$980,559	$1,048,901
Entergy Louisiana	$1,024,433	$1,085,318
Entergy Mississippi	$257,759	$273,338
Entergy New Orleans	$118,620	$125,878
Entergy Texas	$212,935	$225,379
System Energy	$252,397	$267,432

Information for each of the Registrant Subsidiaries qualified pension plans with an accumulated benefit obligation in excess of plan assets as of December 31, 2024 and 2023 was as follows:


2024	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy Texas	System Energy
	(In Thousands)
Accumulated benefit obligation	$304,518	$123,735	$105,285	$58,082	$44,286
Fair value of plan assets	$297,161	$115,446	$103,380	$55,953	$40,146


2023	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Accumulated benefit obligation	$612,788	$658,373	$202,182	$125,878	$70,680	$127,606
Fair value of plan assets	$554,362	$607,471	$196,500	$117,922	$61,495	$109,266

Information for each of the Registrant Subsidiaries qualified pension plans with a projected benefit obligation in excess of plan assets as of December 31, 2024 and 2023 was as follows:


2024	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Projected benefit obligation	$1,009,496	$580,451	$111,659	$108,354	$128,652	$247,186
Fair value of plan assets	$962,101	$559,017	$103,380	$103,727	$120,700	$238,833


2023	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Projected benefit obligation	$1,117,586	$1,173,284	$213,098	$133,949	$146,511	$286,558
Fair value of plan assets	$991,894	$1,058,711	$196,500	$117,922	$128,991	$255,443

Other Postretirement Benefits

Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits.

In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in an Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the Entergy-sponsored retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. The changes affecting active bargaining unit employees were negotiated with the unions prior to implementation, where necessary, and to the extent required by law.

Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy have received regulatory approval to recover accrued other postretirement benefits costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefits costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with employees who work or worked at Grand Gulf.

Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each plan has an undivided beneficial interest in each of the investment accounts in its respective master trust that is maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the plans’ investment accounts. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts.

Components of Net Other Postretirement Benefits Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI

Total 2024, 2023, and 2022 other postretirement benefits (income) costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components:


2024	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Other postretirement costs:
Service cost - benefits earned during the period	$2,569	$2,800	$736	$205	$670	$699
Interest cost on APBO	7,331	7,995	1,945	1,012	2,411	1,593
Expected return on assets	(17,535)	—	(5,486)	(5,915)	(10,156)	(2,912)
Amortization of prior service cost (credit)	2,097	(4,544)	(955)	(916)	(4,371)	(293)
Recognized net (gain) loss	—	(6,952)	61	74	591	—
Net other postretirement benefits income	($5,538)	($701)	($3,699)	($5,540)	($10,855)	($913)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Net gain	($20,074)	($7,273)	($3,915)	($2,217)	($4,683)	($3,476)
Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit (cost)	(2,097)	4,544	955	916	4,371	293
Amortization of net gain (loss)	—	6,952	(61)	(74)	(591)	—
Total	($22,171)	$4,223	($3,021)	($1,375)	($903)	($3,183)
Total recognized as net periodic other postretirement benefits income, regulatory asset, and/or AOCI (before tax)	($27,709)	$3,522	($6,720)	($6,915)	($11,758)	($4,096)


2023	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Other postretirement costs:
Service cost - benefits earned during the period	$2,965	$3,379	$878	$235	$809	$754
Interest cost on APBO	8,002	8,931	2,170	1,160	2,597	1,726
Expected return on assets	(15,113)	—	(4,716)	(5,263)	(8,776)	(2,535)


Amortization of prior service cost (credit)	2,096	(3,804)	(955)	(916)	(4,371)	(293)
Recognized net (gain) loss	171	(7,057)	85	466	914	—
Net other postretirement benefits (income) cost	($1,879)	$1,449	($2,538)	($4,318)	($8,827)	($348)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Prior service credit for the period	$—	($4,434)	$—	$—	$—	$—
Net gain	(23,033)	(458)	(6,883)	(7,606)	(8,790)	(3,942)
Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit (cost)	(2,096)	3,804	955	916	4,371	293
Amortization of net gain (loss)	(171)	7,057	(85)	(466)	(914)	—
Total	($25,300)	$5,969	($6,013)	($7,156)	($5,333)	($3,649)
Total recognized as net periodic other postretirement (income) cost, regulatory asset, and/or AOCI (before tax)	($27,179)	$7,418	($8,551)	($11,474)	($14,160)	($3,997)


2022	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Other postretirement costs:
Service cost - benefits earned during the period	$4,457	$5,633	$1,354	$397	$1,322	$1,239
Interest cost on APBO	5,050	5,770	1,401	694	1,596	1,116
Expected return on assets	(17,930)	—	(5,575)	(5,997)	(10,273)	(3,162)
Amortization of prior service cost (credit)	1,885	(4,630)	(1,772)	(916)	(4,371)	(319)
Recognized net (gain) loss	873	(744)	222	(898)	648	121
Net other postretirement benefits (income) cost	($5,665)	$6,029	($4,370)	($6,720)	($11,078)	($1,005)
Other changes in plan assets and benefit obligations recognized as a regulatory asset and/or AOCI (before tax)
Arising this period:
Prior service cost (credit) for the period	$273	$323	($1,300)	$—	$—	$141
Net (gain) loss	12,894	(65,501)	6,629	17,334	22,323	1,208


Amounts reclassified from regulatory asset and/or AOCI to net periodic benefit cost in the current year:
Amortization of prior service credit (cost)	(1,885)	4,630	1,772	916	4,371	319
Amortization of net gain (loss)	(873)	744	(222)	898	(648)	(121)
Total	$10,409	($59,804)	$6,879	$19,148	$26,046	$1,547
Total recognized as net periodic other postretirement (income) cost, regulatory asset, and/or AOCI (before tax)	$4,744	($53,775)	$2,509	$12,428	$14,968	$542

Other Postretirement Benefits Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet

Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2024 and 2023 are as follows:


2024	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Change in APBO
Balance at January 1	$155,987	$170,139	$41,344	$21,685	$51,617	$33,778
Service cost	2,569	2,800	736	205	670	699
Interest cost	7,331	7,995	1,945	1,012	2,411	1,593
Plan participant contributions	4,200	5,867	696	519	681	1,297
Actuarial gain	(17,007)	(7,273)	(3,008)	(1,063)	(3,763)	(2,897)
Benefits paid	(14,917)	(22,774)	(3,584)	(2,658)	(6,021)	(3,934)
Medicare Part D subsidy received	49	77	14	1	14	17
Balance at December 31	$138,212	$156,831	$38,143	$19,701	$45,609	$30,553
Change in Plan Assets
Fair value of assets at January 1	$274,814	$—	$85,662	$100,536	$161,318	$45,402
Actual return on plan assets	20,602	—	6,393	7,069	11,076	3,491
Employer contributions	(604)	16,907	(23)	134	690	741
Plan participant contributions	4,200	5,867	696	519	681	1,297
Benefits paid	(14,917)	(22,774)	(3,584)	(2,658)	(6,021)	(3,934)
Fair value of assets at December 31	$284,095	$—	$89,144	$105,600	$167,744	$46,997
Funded status	$145,883	($156,831)	$51,001	$85,899	$122,135	$16,444
Amounts recognized in the balance sheet
Non-current assets	$145,883	$—	$51,001	$85,899	$122,135	$16,444
Current liabilities	—	(14,377)	—	—	—	—
Non-current liabilities	—	(142,454)	—	—	—	—


Total funded status	$145,883	($156,831)	$51,001	$85,899	$122,135	$16,444
Amounts recognized in regulatory asset
Prior service cost (credit)	$2,886	$—	($1,727)	($1,066)	($7,419)	($203)
Net loss (gain)	(38,054)	—	(8,791)	(8,134)	9,268	(3,364)
	($35,168)	$—	($10,518)	($9,200)	$1,849	($3,567)
Amounts recognized in AOCI (before tax)
Prior service credit	$—	($8,101)	$—	$—	$—	$—
Net gain	—	(76,030)	—	—	—	—
	$—	($84,131)	$—	$—	$—	$—


2023	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Change in APBO
Balance at January 1	$164,018	$183,126	$44,365	$23,971	$53,482	$35,274
Service cost	2,965	3,379	878	235	809	754
Interest cost	8,002	8,931	2,170	1,160	2,597	1,726
Plan amendments	—	(4,434)	—	—	—	—
Plan participant contributions	3,131	4,317	1,386	374	680	994
Actuarial (gain) loss	(6,403)	(458)	(1,650)	(1,676)	337	(1,075)
Benefits paid	(15,759)	(24,768)	(5,815)	(2,384)	(6,299)	(3,908)
Medicare Part D subsidy received	33	46	10	5	11	13
Balance at December 31	$155,987	$170,139	$41,344	$21,685	$51,617	$33,778
Change in Plan Assets
Fair value of assets at January 1	$255,117	$—	$79,496	$91,140	$148,799	$42,434
Actual return on plan assets	31,743	—	9,949	11,193	17,903	5,402
Employer contributions	582	20,451	646	213	235	480
Plan participant contributions	3,131	4,317	1,386	374	680	994
Benefits paid	(15,759)	(24,768)	(5,815)	(2,384)	(6,299)	(3,908)
Fair value of assets at December 31	$274,814	$—	$85,662	$100,536	$161,318	$45,402
Funded status	$118,827	($170,139)	$44,318	$78,851	$109,701	$11,624
Amounts recognized in the balance sheet
Current liabilities	$—	($15,049)	$—	$—	$—	$—
Non-current liabilities	118,827	(155,090)	44,318	78,851	109,701	11,624
Total funded status	$118,827	($170,139)	$44,318	$78,851	$109,701	$11,624
Amounts recognized in regulatory asset
Prior service cost (credit)	$4,983	$—	($2,682)	($1,982)	($11,790)	($496)
Net loss (gain)	(17,980)	—	(4,815)	(5,843)	14,542	112
	($12,997)	$—	($7,497)	($7,825)	$2,752	($384)


Amounts recognized in AOCI (before tax)
Prior service credit	$—	($12,645)	$—	$—	$—	$—
Net gain	—	(75,709)	—	—	—	—
	$—	($88,354)	$—	$—	$—	$—

The other postretirement plans incurred net actuarial gains during 2024 primarily due to liability gains due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations and an actual return on assets higher than the expected return on assets. The other postretirement plans incurred net actuarial gains during 2023 primarily due to updated demographic assumptions and census data coupled with an actual return on assets much higher than the expected return on assets, partially offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations.

Non-Qualified Pension Plans

Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees.

The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their current and former employees for the non-qualified plans for 2024, 2023, and 2022, was as follows:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2024	$269	$256	$326	$122	$248
2023	$637	$99	$808	$132	$253
2022	$282	$102	$321	$114	$1,320

Included in the 2024 net periodic pension cost above are settlement charges of $55 thousand for Entergy Louisiana related to the lump sum benefits paid out of the plan. Included in the 2023 net periodic pension cost above are settlement charges of $379 thousand and $453 thousand for Entergy Arkansas and Entergy Mississippi, respectively, related to the lump sum benefits paid out of the plan. Included in the 2022 net periodic pension cost above are settlement charges of $1 thousand, $2 thousand, and $1 million for Entergy Louisiana, Entergy Mississippi, and Entergy Texas, respectively, related to the lump sum benefits paid out of the plan.

The projected benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2024 and 2023 was as follows:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2024	$1,721	$1,405	$3,566	$1,143	$2,734
2023	$2,313	$2,574	$3,369	$1,034	$3,762

The accumulated benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2024 and 2023 was as follows:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2024	$1,468	$1,197	$3,322	$939	$2,710
2023	$1,935	$2,494	$3,187	$814	$3,701

The following amounts were recorded on the balance sheet as of December 31, 2024 and 2023:


2024	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Current liabilities	($524)	($190)	($419)	($104)	($386)
Non-current liabilities	(1,197)	(1,215)	(3,147)	(1,039)	(2,348)
Total funded status	($1,721)	($1,405)	($3,566)	($1,143)	($2,734)
Regulatory asset (liability)	$119	$493	$1,292	$9	($3,429)
Accumulated other comprehensive income (before taxes)	$—	$21	$—	$—	$—


2023	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Current liabilities	($276)	($308)	($474)	($106)	($448)
Non-current liabilities	(2,037)	(2,266)	(2,895)	(928)	(3,314)
Total funded status	($2,313)	($2,574)	($3,369)	($1,034)	($3,762)
Regulatory asset (liability)	$857	$1,604	$1,303	$5	($2,526)
Accumulated other comprehensive income (before taxes)	$—	$67	$—	$—	$—

The non-qualified pension plans incurred an actuarial loss during 2024 primarily as a result of liability losses due to differences in recent retirement and lump sum experience relative to actuarial assumptions, as well as salary increases in excess of expectations. The non-qualified pension plans incurred a small actuarial loss during 2023 primarily as a result of liability losses due to differences in recent retirement and lump sum experience relative to actuarial assumptions.

Qualified Pension Settlement Costs

In May 2024, Entergy Corporation entered into a commitment agreement by and between Entergy Corporation, Newport Trust Company, LLC, as independent fiduciary of Entergy Corporation Retirement Plan II for Non-Bargaining Employees, Entergy Corporation Retirement Plan II for Bargaining Employees, Entergy Corporation Retirement Plan III, and Entergy Corporation Retirement Plan IV for Bargaining Employees (the Pension Plans), and the Metropolitan Life Insurance Company (MetLife), under which the Pension Plans

purchased a nonparticipating single premium group annuity contract from MetLife to settle approximately $1.2 billion of benefit liabilities of the Pension Plans.

The group annuity contract primarily covers a population that includes approximately 3,400 non-utility business retirees, joint annuitants, beneficiaries, and alternate payees who commenced benefit payments from the Pension Plans on or before March 1, 2024 (Transferred Participants). MetLife irrevocably guarantees and assumes the sole obligation to make future monthly pension benefit payments to the Transferred Participants as provided under its group annuity contract, with direct payments that began September 1, 2024. The aggregate amount of each Transferred Participant’s payment under the group annuity contract will be equal to the amount of each individual’s payment under the Pension Plans.

The purchase of the group annuity contract was funded directly by assets of the Pension Plans. The transferred pension liability required no additional funding prior to transfer, as the liability was fully funded. As a result of the transaction, Entergy recognized a one-time non-cash pension settlement charge of $328 million in 2024, of which $8 million was recorded at Utility, as described below, and $320 million was recorded at Parent & Other. The $320 million settlement charge at Parent & Other is reflected in Miscellaneous - net in Other income (deductions) on the consolidated income statements.

Year-to-date lump sum benefit payments from Non-Bargaining Plan I, Bargaining Plan I, Non-Bargaining Plan II, and Bargaining Plan II exceeded the sum of the Plans’ service and interest cost, resulting in settlement costs during 2023 and 2022. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of Non-Bargaining Plan I and Bargaining Plan I and incurred settlement costs. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plan’s pension liability. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans each received regulatory approval to defer the expense portion of settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred.

Entergy Mississippi Other Postretirement Benefits

Pursuant to an order from the MPSC, Entergy Mississippi was directed to cease including other postretirement benefit credits in other operation and maintenance expense or allocating to capital expenditures for ratemaking purposes effective January 1, 2024. The credits are being deferred as a regulatory liability. In addition, beginning in July 2024, Entergy Mississippi is recovering the December 31, 2023 other postretirement benefit asset in rate base over five years and accruing a regulatory liability. At December 31, 2024, the balance in these regulatory liability accounts was approximately $7.4 million.

Qualified Pension and Other Postretirement Plans’ Assets

The Plan Administrator’s trust asset investment strategy is to invest the assets in a manner whereby long-term earnings on the assets (plus cash contributions) provide adequate funding for retiree benefit payments. The mix of assets is based on an optimization study that identifies asset allocation targets in order to achieve the maximum return for an acceptable level of risk, while minimizing the expected contributions and pension and postretirement expense.

In the optimization studies, the Plan Administrator formulates assumptions about characteristics, such as expected asset class investment returns, volatility (risk), and correlation coefficients among the various asset

classes. The future market assumptions used in the optimization study are determined by examining historical market characteristics of the various asset classes and making adjustments to reflect future conditions expected to prevail over the study period.

The target asset allocation for pension adjusts dynamically based on the funded status of each plan within the trust. The current targets are shown below. The expectation is that the allocation to fixed income securities will increase as the pension plans’ funded status increases. The following ranges were established to produce an acceptable, economically efficient plan to manage around the targets.

For postretirement assets the target and range asset allocations (as shown below) reflect recommendations made in the latest optimization study. The target asset allocations for postretirement assets adjust dynamically based on the funded status of each sub-account within each trust. The current weighted-average targets shown below represent the aggregate of all targets for all sub-accounts within all trusts.

Entergy’s qualified pension and postretirement weighted-average asset allocations by asset category at December 31, 2024 and 2023 and the target asset allocation and ranges for 2024 are as follows:


Pension Asset Allocation	Target	Range			Actual 2024	Actual 2023
Domestic Equity Securities	22%	18%	to	26%	23%	33%
International Equity Securities	13%	10%	to	16%	13%	18%
Intermediate Fixed Income Securities	4%	3%	to	5%	5%	9%
Long Duration Fixed Income Securities	61%	57%	to	65%	59%	40%
Other	—%	—%	to	10%	—%	—%


Postretirement Asset Allocation	Non-Taxable and Taxable
	Target	Range			Actual 2024	Actual 2023
Domestic Equity Securities	14%	9%	to	19%	16%	28%
International Equity Securities	10%	5%	to	15%	9%	17%
Fixed Income Securities	76%	71%	to	81%	75%	55%
Other	—%	—%	to	5%	—%	—%

In determining its expected long-term rate of return on plan assets used in the calculation of benefit plan costs, Entergy reviews past performance, current and expected future asset allocations, and capital market assumptions of its investment consultant and some investment managers.

The expected long-term rate of return for the qualified pension plans’ assets is based primarily on the geometric average of the historical annual performance of a representative portfolio weighted by the target asset allocation defined in the table above, along with other indications of expected return on assets. The time period reflected is a long-dated period spanning several decades.

The expected long-term rate of return for the non-taxable postretirement trust assets is determined using the same methodology described above for pension assets, but the aggregate asset allocation specific to the non-taxable postretirement assets is used.

For the taxable postretirement trust assets, the investment allocation includes tax-exempt fixed income securities. This asset allocation, in combination with the same methodology employed to determine the expected

return for other postretirement assets (as described above), and with a modification to reflect applicable taxes, is used to produce the expected long-term rate of return for taxable postretirement trust assets.

Concentrations of Credit Risk

Entergy’s investment guidelines mandate the avoidance of risk concentrations. Types of concentrations specified to be avoided include, but are not limited to, investment concentrations in a single entity, type of industry, foreign country, geographic area, and individual security issuance. As of December 31, 2024, all investment managers and assets were materially in compliance with the approved investment guidelines, therefore there were no significant concentrations (defined as greater than 10 percent of plan assets) of credit risk in Entergy’s pension and other postretirement benefits plan assets.

Fair Value Measurements

Accounting standards provide the framework for measuring fair value. That framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements).

The three levels of the fair value hierarchy are described below:

•Level 1 - Level 1 inputs are unadjusted quoted prices for identical assets or liabilities in active markets that the Plan has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by an independent party that uses inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden if it is believed such would be more reflective of fair value. Level 2 inputs include the following:

- quoted prices for similar assets or liabilities in active markets;

- quoted prices for identical assets or liabilities in inactive markets;

- inputs other than quoted prices that are observable for the asset or liability; or

- inputs that are derived principally from or corroborated by observable market data by correlation or other means.

If an asset or liability has a specified (contractual) term, the Level 2 input must be observable for substantially the full term of the asset or liability.

•Level 3 - Level 3 refers to securities valued based on significant unobservable inputs.

Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The following tables set forth by level within the fair value hierarchy, measured at fair value on a recurring basis at December 31, 2024, and December 31, 2023, a summary of the investments held in the master trusts for Entergy’s qualified pension and other postretirement plans in which the Registrant Subsidiaries participate.

Qualified Defined Benefit Pension Plan Trusts


2024	Level 1		Level 2		Level 3	Total
	(In Thousands)
Equity securities:
Corporate stocks:
Preferred	$932	(b)	$—		$—	$932
Common	403,146	(b)	—		—	403,146
Common collective trusts (c)						1,206,983
Fixed income securities:
U.S. Government securities	—		1,145,994	(a)	—	1,145,994
Corporate debt instruments	—		307,666	(a)	—	307,666
Registered investment companies (e)	30,293	(d)	2,735	(d)	—	1,512,994
Other	—		44,691	(f)	—	44,691
Other:
Insurance company general account (unallocated contracts)	—		5,918	(g)	—	5,918
Total investments	$434,371		$1,507,004		$—	$4,628,324
Cash						2,026
Other pending transactions						(133,550)
Less: Other postretirement assets included in total investments						(64,068)
Total fair value of qualified pension assets						$4,432,732


2023	Level 1		Level 2		Level 3	Total
	(In Thousands)
Equity securities:
Corporate stocks:
Preferred	$10,827	(b)	$—		$—	$10,827
Common	715,452	(b)	—		—	715,452
Common collective trusts (c)						2,066,247
Fixed income securities:
U.S. Government securities	—		1,085,231	(a)	—	1,085,231
Corporate debt instruments	—		924,904	(a)	—	924,904
Registered investment companies (e)	34,364	(d)	2,718	(d)	—	657,691
Other	774		78,883	(f)	—	79,657
Other:
Insurance company general account (unallocated contracts)	—		5,899	(g)	—	5,899
Total investments	$761,417		$2,097,635		$—	$5,545,908
Cash						1,488
Other pending transactions						(22,404)


Less: Other postretirement assets included in total investments																								(64,391)
Total fair value of qualified pension assets																								$5,460,601

Other Postretirement Trusts


2024	Level 1		Level 2		Level 3	Total
	(In Thousands)
Equity securities:
Common collective trust (c)						$161,726
Fixed income securities:
U.S. Government securities	$107,547	(b)	$112,780	(a)	$—	220,327
Corporate debt instruments	—		166,208	(a)	—	166,208
Registered investment companies	2,295	(d)	—		—	2,295
Other	—		80,561	(f)	—	80,561
Total investments	$109,842		$359,549		$—	$631,117
Other pending transactions						3,417
Plus: Other postretirement assets included in the investments of the qualified pension trust						64,068
Total fair value of other postretirement assets						$698,602


2023	Level 1		Level 2		Level 3	Total
	(In Thousands)
Equity securities:
Common collective trust (c)						$276,560
Fixed income securities:
U.S. Government securities	$80,219	(b)	$84,521	(a)	$—	164,740
Corporate debt instruments	—		106,523	(a)	—	106,523
Registered investment companies	548	(d)	—		—	548
Other	—		57,511	(f)	—	57,511
Total investments	$80,767		$248,555		$—	$605,882
Other pending transactions						2,868
Plus: Other postretirement assets included in the investments of the qualified pension trust						64,391
Total fair value of other postretirement assets						$673,141

a.Certain fixed income debt securities (corporate, government, and securitized) are stated at fair value as determined by broker quotes.

b.Common stocks, preferred stocks, and certain fixed income debt securities (government) are stated at fair value determined by quoted market prices.

c.The common collective trusts hold investments in accordance with stated objectives. The investment strategy of the trusts is to capture the growth potential of equity markets by replicating the performance of a specified index. The issuer of these funds allows daily trading at the net asset value and trades settle at a later date, with no other trading restrictions. Net asset value per share of common collective trusts estimate fair value. Common collective trusts are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total.

d.Registered investment companies are money market mutual funds with a stable net asset value of one dollar per share. Registered investment companies may hold investments in domestic and international bond markets or domestic equities valued at the daily closing price as reported by the fund. These funds are required to publish their daily net asset value and to transact at that price. The money market mutual funds held by the trusts are deemed to be actively traded. Certain registered investment companies are recorded at contract value, which approximates fair value.

e.Certain of these registered investment companies are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. The issuer of these funds allows daily trading at the net asset value and trades settle at a later date, with no other trading restrictions. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total.

f.The other remaining assets are U.S. municipal and foreign government bonds stated at fair value as determined by broker quotes.

g.The unallocated insurance contract investments are recorded at contract value, which approximates fair value. The contract value represents contributions made under the contract, plus interest, less funds used to pay benefits and contract expenses, and less distributions to the master trust.

Estimated Future Benefit Payments

Based upon the assumptions used to measure Entergy’s qualified pension and other postretirement benefits obligations at December 31, 2024, and including pension and other postretirement benefits attributable to estimated future employee service, Entergy expects that benefits to be paid over the next ten years for the Registrant Subsidiaries for their current and former employees will be as follows:


Estimated Future Qualified Pension Benefits Payments	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Year(s)
2025	$92,997	$99,646	$26,600	$10,879	$22,865	$24,910
2026	$91,164	$94,614	$25,540	$11,107	$22,419	$22,420
2027	$91,175	$93,456	$25,272	$10,658	$21,251	$23,235
2028	$89,535	$95,546	$24,923	$10,775	$20,135	$22,540
2029	$88,244	$93,857	$25,038	$10,242	$20,474	$22,790
2030 - 2034	$437,940	$458,211	$118,197	$50,337	$93,989	$112,086


Estimated Future Non-Qualified Pension Benefits Payments	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
Year(s)
2025	$524	$190	$419	$104	$386


2026	$103	$173	$309	$84	$360
2027	$94	$159	$764	$263	$335
2028	$175	$146	$578	$210	$310
2029	$143	$141	$436	$167	$284
2030 - 2034	$634	$552	$1,582	$609	$1,081


Estimated Future Other Postretirement Benefits Payments	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Year(s)
2025	$12,198	$14,377	$3,329	$2,082	$4,542	$2,645
2026	$11,754	$13,757	$3,218	$1,941	$4,168	$2,434
2027	$11,280	$13,172	$3,109	$1,789	$3,989	$2,339
2028	$11,012	$12,531	$3,110	$1,655	$3,787	$2,288
2029	$10,896	$12,089	$3,014	$1,575	$3,627	$2,278
2030 - 2034	$53,047	$57,646	$14,486	$7,164	$17,113	$11,340

Contributions

The Registrant Subsidiaries currently expect to contribute the following approximate amounts to their qualified pension and other postretirement plans for their current and former employees in 2025:


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Thousands)
Pension Contributions	$35,544	$41,253	$8,064	$5,016	$7,725	$15,668
Other Postretirement Contributions	$529	$14,377	$178	$205	$156	$34

The 2025 required pension contributions will be known with more certainty when the January 1, 2025 valuations are completed, which is expected by April 1, 2025.

Actuarial Assumptions

The significant actuarial assumptions used in determining the pension PBO and the other postretirement benefits APBO as of December 31, 2024 and 2023 were as follows:


	2024	2023
Weighted-average discount rate:
Qualified pension	5.67% - 5.89% Blended 5.75%	5.02% - 5.10% Blended 5.06%
Other postretirement	5.66%	5.01%
Non-qualified pension	5.23%	4.68%
Weighted-average rate of increase in future compensation levels	3.98% - 4.45%	3.98% - 4.40%
Interest crediting rate	4.80%	4.00%


Assumed health care trend rate:
Pre-65	8.15%	6.95%
Post-65	10.13%	7.88%
Ultimate health care cost trend rate	4.75%	4.75%
Year ultimate health care cost trend rate is reached and beyond:
Pre-65	2035	2032
Post-65	2035	2032

The significant actuarial assumptions used in determining the net periodic pension and other postretirement benefits costs for 2024, 2023, and 2022 were as follows:


	2024	2023	2022
Weighted-average discount rate:
Qualified pension:
Service cost	5.08%	5.26%	3.07%
Interest cost	4.97%	5.16%	2.49%
Other postretirement:
Service cost	4.82%	5.00%	3.20%
Interest cost	4.91%	5.09%	2.31%
Non-qualified pension:
Service cost	5.01%	5.31%	4.94%
Interest cost	4.86%	5.30%	5.03%
Weighted-average rate of increase in future compensation levels	3.98% - 4.40%	3.98% - 4.40%	3.98% - 4.40%
Expected long-term rate of return on plan assets:
Pension assets	6.00% - 7.25% Blended 6.75%	7.00%	6.75%
Other postretirement non-taxable assets	6.50% - 7.25%	6.00% - 7.00%	5.75% - 6.75%
Other postretirement taxable assets	5.25%	5.25%	4.75%
Assumed health care trend rate:
Pre-65	6.95%	6.65%	5.65%
Post-65	7.88%	7.50%	5.90%
Ultimate health care cost trend rate	4.75%	4.75%	4.75%
Year ultimate health care cost trend rate is reached and beyond:
Pre-65	2032	2032	2032
Post-65	2032	2032	2032

With respect to the mortality assumptions, Entergy used the Pri-2012 Employee and Healthy Annuitant Table, projected generationally using Scale MP-2021 with Aon’s Endemic Adjustment, in determining its December 31, 2024 and 2023 pension plans’ PBOs and the Pri.H 2012 (headcount weighted) Employee and Healthy Annuitant Table, projected generationally using Scale MP-2021 with Aon’s Endemic Adjustment, in determining its December 31, 2024 and 2023 other postretirement benefits APBO.

Defined Contribution Plans

Entergy sponsors the Savings Plan of Entergy Corporation and Subsidiaries (System Savings Plan). The System Savings Plan is a defined contribution plan covering eligible employees of Entergy and certain of its subsidiaries. The participating Entergy subsidiary makes matching contributions to the System Savings Plan for all eligible participating employees in an amount equal to either 70% or 100% of the participants’ basic contributions, up to 6% of their eligible earnings per pay period. The matching contribution is allocated to investments as directed by the employee.

Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries VI (Savings Plan VI) (established in April 2007) and the Savings Plan of Entergy Corporation and Subsidiaries VII (Savings Plan VII) (established in April 2007) to which matching contributions are also made. The plans are defined contribution plans that cover eligible employees, as defined by each plan, of Entergy and certain of its subsidiaries. Effective December 31, 2023, employees participating in Savings Plan VI and Savings Plan VII were transferred into the System Savings Plan when Savings Plan VI and Savings Plan VII merged into the System Savings Plan.

Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries VIII (established January 2021) and the Savings Plan of Entergy Corporation and Subsidiaries IX (established January 2021) to which company contributions are made. The participating Entergy subsidiary makes matching contributions to these defined contribution plans for all eligible participating employees in an amount equal to 100% of the participants’ basic contributions, up to 5% of their eligible earnings per pay period. Eligible participants may also receive a discretionary annual company contribution up to 4% of the participant’s eligible earnings (subject to vesting).

Entergy’s subsidiaries’ contributions to defined contribution plans collectively were $72.3 million in 2024, $65.1 million in 2023, and $62.1 million in 2022. The majority of the contributions were to the System Savings Plan.

The Registrant Subsidiaries’ 2024, 2023, and 2022 contributions to defined contribution plans for their employees were as follows:


Year	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Thousands)
2024	$6,822	$8,784	$4,048	$1,584	$3,907
2023	$5,866	$7,757	$3,534	$1,383	$3,380
2022	$5,124	$7,138	$3,194	$1,223	$2,938

NOTE 12. STOCK-BASED COMPENSATION

Note 12 to the financial statements is not applicable to the Registrant Subsidiaries.

NOTE 13. BUSINESS SEGMENT INFORMATION

Registrant Subsidiaries

Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has one operating and reportable segment, an integrated utility business which includes the generation,

transmission, and distribution of electric power; and operation of a small natural gas distribution business at each of Entergy Louisiana and Entergy New Orleans. Revenue for each integrated utility business is primarily derived from retail electric sales. System Energy has one operating and reportable segment, which is an electricity generation business. System Energy’s only source of revenue is the sale of electric power and capacity generated from its 90% interest in the Grand Gulf nuclear plant to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. The chief operating decision maker for the Registrant Subsidiaries is the respective president and chief executive officer for the Utility operating companies and the president for System Energy. Each chief operating decision maker assesses financial performance on an entity-wide basis and decides how to allocate resources based on net income that also is reported on the income statement for each of the Registrant Subsidiaries as net income. Net income is used in the annual planning process and to monitor budget versus actual results on a monthly basis and each Registrant Subsidiary’s earned return on common equity in assessing financial performance. Each chief operating decision maker is only provided with the consolidated financial results for the respective Registrant Subsidiary. All segment financial information for the Registrant Subsidiaries is as reported on the respective financial statements for each of the Registrant Subsidiaries.

NOTE 14. ACQUISITIONS AND DISPOSITIONS

Acquisitions

Sunflower Solar

In November 2018, Entergy Mississippi entered into an agreement for the purchase of an approximately 100 MW solar photovoltaic facility to be sited on approximately 1,000 acres in Sunflower County, Mississippi. The project, Sunflower Solar facility, was being built by Sunflower County Solar Project, LLC, an indirect subsidiary of Recurrent Energy, LLC. In December 2018, Entergy Mississippi filed a joint petition with Sunflower County Solar Project with the MPSC for Sunflower County Solar Project to construct and for Entergy Mississippi to acquire and thereafter own, operate, improve, and maintain the solar facility. In March 2020, Entergy Mississippi filed supplemental testimony addressing questions and observations raised in August 2019 by consultants retained by the Mississippi Public Utilities Staff and proposing an alternative structure for the transaction that would reduce its cost. In April 2020 the MPSC issued an order approving certification of the Sunflower Solar facility, subject to certain conditions, including: (i) that Entergy Mississippi pursue a tax equity partnership structure through which the partnership would acquire and own the facility under the build-own-transfer agreement and (ii) that if Entergy Mississippi does not consummate the partnership structure under the terms of the order, there will be a cap of $136 million on the level of recoverable costs. In April 2022, Entergy Mississippi confirmed mechanical completion of the Sunflower Solar facility. Pursuant to the MPSC’s April 2020 order, MS Sunflower Partnership, LLC was formed for the tax equity partnership with Entergy Mississippi as its managing member. In May 2022 both Entergy Mississippi and the tax equity investor made capital contributions to the tax equity partnership that were then used to make an initial payment of $105 million for acquisition of the facility. Substantial completion of the Sunflower Solar facility was accepted by Entergy Mississippi in September 2022. Commercial operation at the Sunflower Solar facility commenced in September 2022. In April 2023 both Entergy Mississippi and the tax equity investor made additional capital contributions to the tax equity partnership that were then used to make the substantial completion payment of $30 million for acquisition of the facility. The final payment of $5 million for acquisition of the facility was made in October 2023.

NOTE 15. RISK MANAGEMENT AND FAIR VALUES

Market Risk

In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk associated with the price of fuel.

The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use commodity and financial instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers.

Derivatives

Entergy designates a significant portion of its derivative instruments as normal purchase/normal sale transactions due to their physical settlement provisions, including power purchase and sales agreements, fuel purchase agreements, and capacity contracts. Certain derivative instruments do not qualify for designation as normal purchase/normal sale transactions due to their financial settlement provisions. See further discussion below regarding the accounting for these derivative instruments.

Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2024 is 10 months for Entergy Mississippi. The total volume of natural gas swaps and options outstanding as of December 31, 2024 is 9,603,850 MMBtu for Entergy and Entergy Mississippi. As of December 31, 2024, Entergy Louisiana and Entergy New Orleans had no outstanding natural gas swaps or options. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral.

During the second quarter 2024, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2024 through May 31, 2025. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2024 is 13,991 GWh for Entergy Arkansas, 24,896 GWh for Entergy Louisiana, 9,297 GWh for Entergy Mississippi, 2,460 GWh for Entergy New Orleans, and 8,579 GWh for Entergy Texas. Credit support for financial

transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by Entergy’s non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of December 31, 2024 and 2023. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2024 and for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of December 31, 2023.

The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2024 and 2023 are shown in the tables below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.


Instrument	Balance Sheet Location	Gross Fair Value (a)	Offsetting Position (b)	Net Fair Value (c) (d)	Registrant
		(In Millions)
2024
Assets:
Natural gas swaps	Prepayments and other	$1.6	$—	$1.6	Entergy Mississippi

Financial transmission rights	Prepayments and other	$8.6	($0.1)	$8.5	Entergy Arkansas
Financial transmission rights	Prepayments and other	$8.7	($0.1)	$8.6	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.3	$—	$1.3	Entergy New Orleans
Financial transmission rights	Prepayments and other	$2.0	($0.1)	$1.9	Entergy Texas

Liabilities:
Financial transmission rights	Other current liabilities	($0.4)	$0.9	$0.5	Entergy Mississippi

2023
Assets:
Financial transmission rights	Prepayments and other	$6.0	$—	$6.0	Entergy Arkansas
Financial transmission rights	Prepayments and other	$9.8	$—	$9.8	Entergy Louisiana
Financial transmission rights	Prepayments and other	$1.4	$—	$1.4	Entergy Mississippi
Financial transmission rights	Prepayments and other	$1.1	$—	$1.1	Entergy New Orleans
Financial transmission rights	Prepayments and other	$2.7	($0.3)	$2.4	Entergy Texas

Liabilities:


Natural gas swaps and options	Other current liabilities	$0.4	$—	$0.4	Entergy Louisiana
Natural gas swaps	Other current liabilities	$10.1	$—	$10.1	Entergy Mississippi
Natural gas swaps	Other current liabilities	$0.6	$—	$0.6	Entergy New Orleans

a.Represents the gross amounts of recognized assets/liabilities

b.Represents the netting of fair value balances with the same counterparty

c.Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets

d.Excludes letters of credit posted with MISO to cover financial transmission rights exposure in the amount of $0.5 million for Entergy Arkansas, $0.1 million for Entergy Louisiana, $0.8 million for Entergy Mississippi, $0.1 million for Entergy New Orleans, and $0.3 million for Entergy Texas as of December 31, 2024 and in the amount of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas as of December 31, 2023

The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2024, 2023, and 2022 are as follows:

Instrument

Income Statement Location

Amount of gain (loss) recorded in the income statement

Registrant

(In Millions)

2024

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

(a)

$7.0

Entergy Mississippi

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

(a)

$0.5

Entergy New Orleans

Financial transmission rights

Purchased power expense

(b)

$59.8

Entergy Arkansas

Financial transmission rights

Purchased power expense

(b)

$71.7

Entergy Louisiana

Financial transmission rights

Purchased power expense

(b)

$7.5

Entergy Mississippi

Financial transmission rights

Purchased power expense

(b)

$6.9

Entergy New Orleans

Financial transmission rights

Purchased power expense

(b)

$17.8

Entergy Texas

2023

Natural gas swaps and options

Fuel, fuel-related expenses, and gas purchased for resale

(a)

($8.4)

Entergy Louisiana

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

(a)

($42.9)

Entergy Mississippi

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

(a)

($3.0)

Entergy New Orleans

Financial transmission rights

Purchased power expense

(b)

$25.8

Entergy Arkansas

Financial transmission rights

Purchased power expense

(b)

$60.4

Entergy Louisiana

Financial transmission rights

Purchased power expense

(b)

$13.7

Entergy Mississippi

Financial transmission rights

Purchased power expense

(b)

$6.4

Entergy New Orleans

Financial transmission rights

Purchased power expense

(b)

$17.3

Entergy Texas

2022

Natural gas swaps and options

Fuel, fuel-related expenses, and gas purchased for resale

(a)

$21.4

Entergy Louisiana

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

(a)

$53.6

Entergy Mississippi

Natural gas swaps

Fuel, fuel-related expenses, and gas purchased for resale

(a)

($1.2)

Entergy New Orleans

Financial transmission rights

Purchased power expense

(b)

$106.5

Entergy Arkansas

Financial transmission rights

Purchased power expense

(b)

$48.5

Entergy Louisiana

Financial transmission rights

Purchased power expense

(b)

$10.4

Entergy Mississippi

Financial transmission rights

Purchased power expense

(b)

$3.7

Entergy New Orleans

Financial transmission rights

Purchased power expense

(b)

$6.3

Entergy Texas

a.Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms.

b.Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

Fair Values

The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments.

Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value.

Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs.

The three levels of the fair value hierarchy are:

•Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing

information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase.

•Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following:

–quoted prices for similar assets or liabilities in active markets;

–quoted prices for identical assets or liabilities in inactive markets;

–inputs other than quoted prices that are observable for the asset or liability; or

–inputs that are derived principally from or corroborated by observable market data by correlation or other means.

Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs.

•Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights.

The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer. The Accounting group reports to the Chief Accounting Officer.

The following tables set forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2024 and December 31, 2023. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels.

Entergy Mississippi


2024	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$155.5	$—	$—	$155.5


Natural gas swaps	1.6	—	—	1.6
	$157.1	$—	$—	$157.1

Liabilities:
Financial transmission rights	$—	$—	$0.5	$0.5


2023	Level 1	Level 2	Level 3	Total
	(In Millions)
Assets:
Temporary cash investments	$6.6	$—	$—	$6.6
Storm reserve escrow account	0.7	—	—	0.7
Financial transmission rights	—	—	1.4	1.4
	$7.3	$—	$1.4	$8.7

Liabilities:
Natural gas swaps	$10.1	$—	$—	$10.1

The following table sets forth a reconciliation of changes in the net assets (liabilities) for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the year ended December 31, 2024.


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1, 2024	$6.0	$9.8	$1.4	$1.1	$2.4
Issuances of financial transmission rights	17.6	21.6	3.9	2.8	7.3
Gains included as a regulatory liability/asset	44.7	48.9	1.7	4.3	10.0
Settlements	(59.8)	(71.7)	(7.5)	(6.9)	(17.8)
Balance as of December 31, 2024	$8.5	$8.6	($0.5)	$1.3	$1.9

The following table sets forth a reconciliation of changes in the net assets for the fair value of financial transmission rights classified as Level 3 in the fair value hierarchy for the year ended December 31, 2023.


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas
	(In Millions)
Balance as of January 1, 2023	$10.3	$7.3	$0.6	$0.8	$0.1
Issuances of financial transmission rights	20.6	18.1	1.3	1.4	0.2
Gains included as a regulatory liability/asset	0.9	44.8	13.2	5.3	19.4


Settlements	(25.8)	(60.4)	(13.7)	(6.4)	(17.3)
Balance as of December 31, 2023	$6.0	$9.8	$1.4	$1.1	$2.4

NOTE 16. DECOMMISSIONING TRUST FUNDS

Note 16 to the financial statements is not applicable to Entergy Mississippi.

NOTE 17. VARIABLE INTEREST ENTITIES

Note 17 to the financial statements is not applicable to the presentation of the FERC Form 1.

NOTE 18. TRANSACTIONS WITH AFFILIATES

Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis.

The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates.

Intercompany Revenues


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Millions)
2024	$111.8	$312.8	$1.0	$—	$—	$583.3
2023	$125.2	$317.6	$1.0	$—	$0.7	$588.4
2022	$127.5	$354.0	$1.0	$—	$18.9	$658.8

Intercompany Operating Expenses


	Entergy Arkansas	Entergy Louisiana	Entergy Mississippi	Entergy New Orleans	Entergy Texas	System Energy
	(In Millions)
2024	$540.6	$649.3	$339.6	$293.9	$319.4	$166.6
2023	$585.8	$719.8	$345.2	$302.5	$316.8	$179.0
2022	$617.4	$770.2	$356.1	$341.7	$321.4	$215.0

Intercompany Interest and Investment Income

Entergy Arkansas

Entergy Louisiana

Entergy Mississippi

Entergy New Orleans

Entergy Texas

System Energy


	(In Millions)
2024	$2.2	$315.4	$0.4	$0.2	$2.7	$0.8
2023	$0.7	$303.2	$0.2	$1.0	$1.8	$0.6
2022	$0.1	$186.1	$0.1	$0.1	$0.3	$0.3

NOTE 19. SUBSEQUENT EVENTS

Management has evaluated the impact of events after December 31, 2024 up to February 18, 2025, the date that Entergy Mississippi’s U.S. GAAP financial statements were issued and has updated such evaluations for disclosure purposes through April 15, 2025. These financial statements include all necessary adjustments and disclosures resulting from these evaluations.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote. Report data on a year-to-date basis.
Line No.	Item (a)	Unrealized Gains and Losses on Available-For-Sale Securities (b)	Minimum Pension Liability Adjustment (net amount) (c)	Foreign Currency Hedges (d)	Other Adjustments (e)	Other Cash Flow Hedges Interest Rate Swaps (f)	Other Cash Flow Hedges [Specify] (g)	Totals for each category of items recorded in Account 219 (h)	Net Income (Carried Forward from Page 116, Line 78) (i)	Total Comprehensive Income (j)
1	Balance of Account 219 at Beginning of Preceding Year
2	Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3	Preceding Quarter/Year to Date Changes in Fair Value
4	Total (lines 2 and 3)								193,256,754
5	Balance of Account 219 at End of Preceding Quarter/Year
6	Balance of Account 219 at Beginning of Current Year
7	Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8	Current Quarter/Year to Date Changes in Fair Value
9	Total (lines 7 and 8)								255,834,808
10	Balance of Account 219 at End of Current Quarter/Year

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION
Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.
Line No.	Classification (a)	Total Company For the Current Year/Quarter Ended (b)	Electric (c)	Gas (d)	Other (Specify) (e)	Other (Specify) (f)	Other (Specify) (g)	Common (h)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlantInServiceAbstract In Service
3	UtilityPlantInServiceClassified Plant in Service (Classified)	7,168,134,601	7,168,134,601
4	UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases	(a) 43,125,472	43,125,472
5	UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold
6	UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified	416,048,666	416,048,666
7	UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified
8	UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7)	7,627,308,739	7,627,308,739
9	UtilityPlantLeasedToOthers Leased to Others
10	UtilityPlantHeldForFutureUse Held for Future Use	220,455	220,455
11	ConstructionWorkInProgress Construction Work in Progress	510,924,980	510,924,980
12	UtilityPlantAcquisitionAdjustment Acquisition Adjustments	83,828,314	83,828,314
13	UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12)	8,222,282,488	8,222,282,488
14	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion	(b) 2,322,111,180	2,322,111,180
15	UtilityPlantNet Net Utility Plant (13 less 14)	5,900,171,308	5,900,171,308
16	DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17	AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service:
18	DepreciationUtilityPlantInService Depreciation	2,004,781,099	2,004,781,099
19	AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService Amortization and Depletion of Producing Natural Gas Land and Land Rights
20	AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService Amortization of Underground Storage Land and Land Rights
21	AmortizationOfOtherUtilityPlantUtilityPlantInService Amortization of Other Utility Plant	(c) 291,600,116	291,600,116
22	DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21)	2,296,381,215	2,296,381,215
23	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract Leased to Others
24	DepreciationUtilityPlantLeasedToOthers Depreciation
25	AmortizationAndDepletionUtilityPlantLeasedToOthers Amortization and Depletion
26	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers Total Leased to Others (24 & 25)
27	DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract Held for Future Use
28	DepreciationUtilityPlantHeldForFutureUse Depreciation	6,808	6,808
29	AmortizationUtilityPlantHeldForFutureUse Amortization
30	DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29)	6,808	6,808
31	AbandonmentOfLeases Abandonment of Leases (Natural Gas)
32	AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment	25,723,157	25,723,157
33	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32)	(d) 2,322,111,180	2,322,111,180

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: UtilityPlantInServicePropertyUnderCapitalLeases

Includes Operating Leases recorded in accordance with FASB ASU No. 2016-02, Leases, as provided for in FERC Docket No. AI19-1-000.

(b) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility

Includes a debit balance for removal costs of $184,788,177.

(c) Concept: AmortizationOfOtherUtilityPlantUtilityPlantInService

Includes accumulated provision for amortization of intangible assets.

(d) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility

Includes a debit balance for removal costs of $184,788,177.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No.	Description of item (a)	Balance Beginning of Year (b)	Changes during Year Additions (c)	Changes during Year Amortization (d)	Changes during Year Other Reductions (Explain in a footnote) (e)	Balance End of Year (f)
1	Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1)
2	Fabrication
3	Nuclear Materials
4	Allowance for Funds Used during Construction
5	(Other Overhead Construction Costs, provide details in footnote)
6	SUBTOTAL (Total 2 thru 5)
7	Nuclear Fuel Materials and Assemblies
8	In Stock (120.2)
9	In Reactor (120.3)
10	SUBTOTAL (Total 8 & 9)
11	Spent Nuclear Fuel (120.4)
12	Nuclear Fuel Under Capital Leases (120.6)
13	(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)
14	TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)
15	Estimated Net Salvage Value of Nuclear Materials in Line 9
16	Estimated Net Salvage Value of Nuclear Materials in Line 11
17	Est Net Salvage Value of Nuclear Materials in Chemical Processing
18	Nuclear Materials held for Sale (157)
19	Uranium
20	Plutonium
21	Other (Provide details in footnote)
22	TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21)

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
Report below the original cost of electric plant in service according to the prescribed accounts. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of the prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No.	Account (a)	Balance Beginning of Year (b)	Additions (c)	Retirements (d)	Adjustments (e)	Transfers (f)	Balance at End of Year (g)
1	1. INTANGIBLE PLANT
2	(301) Organization
3	(302) Franchise and Consents
4	(303) Miscellaneous Intangible Plant	408,950,690	22,470,917	1,694,681			429,726,926
5	TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)	408,950,690	22,470,917	1,694,681			429,726,926
6	2. PRODUCTION PLANT
7	A. Steam Production Plant
8	(310) Land and Land Rights	2,001,731					2,001,731
9	(311) Structures and Improvements	54,345,042	938,908	628,588			54,655,362
10	(312) Boiler Plant Equipment	278,790,314	3,082,352	2,482,993			279,389,673
11	(313) Engines and Engine-Driven Generators
12	(314) Turbogenerator Units	106,244,210	884,156	121,228			107,007,138
13	(315) Accessory Electric Equipment	38,295,120	425,009	105,646			38,614,483
14	(316) Misc. Power Plant Equipment	7,991,222	374,359	36,341			8,329,240
15	(317) Asset Retirement Costs for Steam Production	1,834,819	11,852,682				13,687,501
16	TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)	489,502,458	17,557,466	3,374,796			503,685,128
17	B. Nuclear Production Plant
18	(320) Land and Land Rights
19	(321) Structures and Improvements
20	(322) Reactor Plant Equipment
21	(323) Turbogenerator Units
22	(324) Accessory Electric Equipment
23	(325) Misc. Power Plant Equipment
24	(326) Asset Retirement Costs for Nuclear Production
25	TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)
26	C. Hydraulic Production Plant
27	(330) Land and Land Rights
28	(331) Structures and Improvements
29	(332) Reservoirs, Dams, and Waterways
30	(333) Water Wheels, Turbines, and Generators
31	(334) Accessory Electric Equipment
32	(335) Misc. Power Plant Equipment
33	(336) Roads, Railroads, and Bridges
34	(337) Asset Retirement Costs for Hydraulic Production
35	TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)
36	D. Other Production Plant
37	(340) Land and Land Rights	4,253,086				5,517,735	9,770,821
38	(341) Structures and Improvements	332,942,766	3,788,055	766,833			335,963,988
39	(342) Fuel Holders, Products, and Accessories	8,645,077	343,907	106,993			8,881,991
40	(343) Prime Movers	372,736,548	36,077,391	3,422,225			405,391,714
41	(344) Generators	222,048,705	2,853,013	10,097,963			214,803,755
42	(345) Accessory Electric Equipment	47,109,661	1,502,407	383,669			48,228,399
43	(346) Misc. Power Plant Equipment	8,107,784	1,368,068	7,354			9,468,498
44	(347) Asset Retirement Costs for Other Production
44.1	(348) Energy Storage Equipment - Production
45	TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)	995,843,627	45,932,841	14,785,037		5,517,735	1,032,509,166
46	TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)	1,485,346,085	63,490,307	18,159,833		5,517,735	1,536,194,294
47	3. Transmission Plant
48	(350) Land and Land Rights	111,489,850	6,079,904			5,495,945	112,073,809
48.1	(351) Energy Storage Equipment - Transmission
49	(352) Structures and Improvements	82,102,600	10,530,877	36,764		321,648	92,918,361
50	(353) Station Equipment	790,577,684	49,656,315	1,745,282		528,473	839,017,190
51	(354) Towers and Fixtures	60,680,481		18,250			60,662,231
52	(355) Poles and Fixtures	527,345,683	49,727,429	1,394,068			575,679,044
53	(356) Overhead Conductors and Devices	374,688,248	6,230,529	786,525			380,132,252
54	(357) Underground Conduit	1,311					1,311
55	(358) Underground Conductors and Devices	6,310					6,310
56	(359) Roads and Trails
57	(359.1) Asset Retirement Costs for Transmission Plant
58	TOTAL Transmission Plant (Enter Total of lines 48 thru 57)	1,946,892,167	122,225,054	3,980,889		4,645,824	2,060,490,508
59	4. Distribution Plant
60	(360) Land and Land Rights	33,548,655	8,090,977	450,734		21,790	41,167,108
61	(361) Structures and Improvements	34,224,123	1,113,046	10,903		321,648	35,004,618
62	(362) Station Equipment	486,041,053	29,287,434	1,341,992		528,473	513,458,022
63	(363) Energy Storage Equipment – Distribution
64	(364) Poles, Towers, and Fixtures	498,609,276	46,703,111	6,668,309			538,644,078
65	(365) Overhead Conductors and Devices	582,939,650	36,295,445	5,867,425			613,367,670
66	(366) Underground Conduit	61,402,109	6,184,594	152,116			67,434,587
67	(367) Underground Conductors and Devices	123,016,254	11,325,366	1,242,119			133,099,501
68	(368) Line Transformers	730,499,134	64,258,171	8,680,653			786,076,652
69	(369) Services	199,945,187	4,590,012	341,826			204,193,373
70	(370) Meters	164,263,595	13,633,211	83,951			177,812,855
71	(371) Installations on Customer Premises	55,581,678	4,009,330	2,324,275			57,266,733
72	(372) Leased Property on Customer Premises
73	(373) Street Lighting and Signal Systems	101,585,176	14,139,743	1,881,079			113,843,840
74	(374) Asset Retirement Costs for Distribution Plant
75	TOTAL Distribution Plant (Enter Total of lines 60 thru 74)	3,071,655,890	239,630,440	29,045,382		871,911	3,281,369,037
76	5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77	(380) Land and Land Rights
78	(381) Structures and Improvements
79	(382) Computer Hardware
80	(383) Computer Software
81	(384) Communication Equipment
82	(385) Miscellaneous Regional Transmission and Market Operation Plant
83	(386) Asset Retirement Costs for Regional Transmission and Market Oper
84	TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85	6. General Plant
86	(389) Land and Land Rights	7,835,243					7,835,243
87	(390) Structures and Improvements	159,250,893	4,753,081	2,662,558			161,341,416
88	(391) Office Furniture and Equipment	21,596,326	1,852,772	6,598,737			16,850,361
89	(392) Transportation Equipment	261,640		105,909			155,731
90	(393) Stores Equipment	30,317					30,317
91	(394) Tools, Shop and Garage Equipment	11,652,635	978,744				12,631,379
92	(395) Laboratory Equipment	4,412,313					4,412,313
93	(396) Power Operated Equipment	64,407					64,407
94	(397) Communication Equipment	66,025,802	3,861,744	212,476			69,675,070
95	(398) Miscellaneous Equipment	3,031,138	375,127				3,406,265
96	SUBTOTAL (Enter Total of lines 86 thru 95)	274,160,714	11,821,468	9,579,680			276,402,502
97	(399) Other Tangible Property
98	(399.1) Asset Retirement Costs for General Plant
99	TOTAL General Plant (Enter Total of lines 96, 97, and 98)	274,160,714	11,821,468	9,579,680			276,402,502
100	TOTAL (Accounts 101 and 106)	7,187,005,546	459,638,186	62,460,465			7,584,183,267
101	(102) Electric Plant Purchased (See Instr. 8)
102	(Less) (102) Electric Plant Sold (See Instr. 8)
103	(103) Experimental Plant Unclassified
104	TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)	7,187,005,546	459,638,186	62,460,465			7,584,183,267

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No.	LesseeName Name of Lessee (a)	IndicationOfAssociatedCompany * (Designation of Associated Company) (b)	LeaseDescription Description of Property Leased (c)	CommissionAuthorization Commission Authorization (d)	ExpirationDateOfLease Expiration Date of Lease (e)	ElectricPlantLeasedToOthers Balance at End of Year (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47	TOTAL

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No.	ElectricPlantHeldForFutureUseDescription Description and Location of Property (a)	ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate Date Originally Included in This Account (b)	ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate Date Expected to be used in Utility Service (c)	ElectricPlantHeldForFutureUse Balance at End of Year (d)
1	Land and Rights:
2	Land and Land Rights Under $250,000			205,522
3
21	Other Property:
22	Other Property Under $250,000			14,933
47	TOTAL			220,455

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
Report below descriptions and balances at end of year of projects in process of construction (107). Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts). Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No.	ConstructionWorkInProgressProjectDescription Description of Project (a)	ConstructionWorkInProgress Construction work in progress - Electric (Account 107) (b)
1	2020 - SOUTHAVEN - HORN LAKE/GREENB	137,501
2	2020 - SOUTHAVEN - PLUM POINT - CH	397,629
3	2021 - SOUTHAVEN - PLUM POINT - I55	231,225
4	2022 Madison MB04 50V0007 Repl Regu	112,902
5	2022 Woodrow Wilson Relocation	228,100
6	2023-C6MD303319-Mannsdale URD Dist	1,739,198
7	2023-C6MD303323-Circuit 1 Mannsdale	934,363
8	2023-SOUTHAVEN-PLUM POINT- 1R10 -	417,245
9	2024 - Madison - Flora - 6D01/6D07	101,167
10	2024- F1PPUX4990- UG TIE B/W AA01 &	322,368
11	2025-Improve-Coldwater-1L05-SE23-00	472,446
12	Byhalia Dist ROW	326,534
13	CLINTON - FAILURE - CONV. 415815862	156,721
14	CUSTOMR - Customer Requested Projec	217,095
15	Downtown Jackson - Replace 1500 KVA	338,556
16	EMI 2024 November Storm Number	285,128
17	EMI Disturbance 24 Francine	8,823,954
18	FERNWOOD - AIRPORT-FERNWOOD RD - RE	116,640
19	GM-Vicksburg SE Guild 5F03-N6, FSW1	4,188,370
20	GM-Vicksburg SE Guild 5F03-N7, N8,	250,690
21	GM-Vicksburg SE Guild 5F03-R8 part	564,317
22	HIGHWAY - 2023 - Southaven - Plum P	185,844
23	HIGHWAY -2023 - Southaven - Plum Po	161,710
24	IMPROVE - 2024 - Senatobia - 1L04 -	600,301
25	Improve -2024 - SH25-013A - Hernand	137,792
26	IMPROVE-2023- PINE TREE -F1PPU51280	851,075
27	IMPROVE-2023-PINE TREE- AP02- F1PPU	229,801
28	IMPROVE-2023-PINE TREE-AP01/AP02/AP	2,154,971
29	IMPROVE-2023-PINETREE-AP02/AP04/1Y0	288,072
30	Improve-2024-Rankin-FA01- RK24-001V	394,105
31	IMPROVE-2025-Hernando-1Y05-SH24-006	352,659
32	Mannsdale T&D D-Scoping	264,861
33	MS FEEDER INVESTMENT, 2023, CLINTON	957,276
34	MS FEEDER INVESTMENT, 2023, UTICA,	4,034,503
35	Pine Tree Substation T&D D-Scoping	1,075,344
36	PSK405-EML-Grenada Industrial Park	1,344,984
37	PSK405-EML-RK20-010V Magee 7N01 Pha	1,722,840
38	Relocate Facilities W Capitol St	744,883
39	ROW Magee RK20-010V	679,244
40	SLI JOB - 2020 - SOUTHAVEN - PLUM P	614,068
41	SLI JOB - 2023 - SOUTHAVEN - PLUM P	403,963
42	SLI JOB - FC21M053 - FOCUS - FA05 -	112,835
43	SLI JOB - FC23M051-FOCUS-6N08-6N08	234,351
44	SLI JOB - FERNWOOD - AIRPORT-FERNWO	199,024
45	SLI JOB - HIGHWAY - 2023 - Southave	103,650
46	SLI JOB - HIGHWAY - 2023- Southaven	145,643
47	SLI JOB - JACKSON -HWY 18 - TV ROAD	1,722,505
48	SLI JOB - PEARL - GGO1 - RECONDUCT	254,977
49	SLI JOB -2024 - VBURG - NORTH VICKS	169,989
50	SLI JOB -HIGHWAY -2023 - Southaven	219,195
51	SLI JOB-- ROBINSONVILLE-1001 SCHULZ	114,256
52	SLI JOB-GRENADA-LED CONVERSION-CITY	126,691
53	UPIC-BYRAM-STATESMAN DRIVE-ARROWHEA	147,177
54	UPIC-Flowood-E. Metro Pkwy-Flowood	258,170
55	UPIC-Hernando-McInvale-M&R Builders	258,018
56	UPIC-Jackson-Livingston Rd-VLP, LLC	225,930
57	UPIC-PEARL-EAST METRO PKWY-MS DEVEL	170,450
58	UPIC-Southaven-Tchulahoma Rd-M&R Bu	139,707
59	VB22-003T Bovina Tie to Vicksburg -	149,289
60	OTHER DISTRIBUTION LINES PLANT	2,488,902
61	2024 Dist Capital Tools EML	742,620
62	2024 Documentum Upgrade & OpenPass	159,309
63	Accr Prx Code-Dist Cap EML	328,809
64	BA Insight Licenses	118,600
65	Best Bill Analysis - EMI	107,425
66	Clinton KAST Center Training Equipm	373,067
67	Complex Billing System	112,742
68	DACT Enhancements	235,424
69	Distribution Resiliency Plan	1,066,676
70	EMI: Camlin Pilot Franklin EHV	426,630
71	EML Nissan Vehicles EV	114,783
72	ESI - LIGHTING REMEDIATION PROJECT	405,366
73	EV Charging Cleveland	190,526
74	EV Charging Greenville	190,526
75	EV Charging Magee	190,526
76	EV Charging Natchez	190,526
77	GIS Enhancement	103,916
78	GMS Software Upgrade	466,534
79	Helicopter acquisition EML	2,185,699
80	LFN - Environmental Health Safety S	214,321
81	Little Rock CrowdStrike Software	225,450
82	Micro Segmentation	155,841
83	Miss. Signage Rebranding Costs	558,001
84	PD Capital Prioritization ESI	451,395
85	Prevailing Wage & Apprenticeship Tr	107,642
86	ROCC Buildout Continuation	195,971
87	Substation Modification Eastern '25	110,426
88	TCC North Mapboard	114,923
89	TCC South Mapboard	114,923
90	OTHER GENERAL & INTANGIBLE PLANT	1,399,917
91	A1A - GE LTSA Budget Capital	3,387,741
92	CO1 - Choctaw Emergency Generator	1,253,699
93	CO1 LTSA Capitalization CT 101	7,366,595
94	CO1 LTSA Capitalization- CT-201	1,658,598
95	CO1 LTSA Capitalization- CT-301	1,987,074
96	EMI - Delta Solar	1,864,990
97	EML - Penton Solar	3,066,310
98	EML Delta Blues CCCT	139,245,938
99	EML Grain Belt Express Wind Asset	246,677
100	EML Lakeover CCGT	8,446,517
101	HN1 - Hinds LTSA Capital	22,945,897
102	Vicksburg Advanced Power Station	91,526,432
103	OTHER PRODUCTION PLANT	123,078
104	Andes Expansion	5,942,251
105	Andes Substation	10,100,060
106	Belzoni: Install circuit switchers,	1,581,345
107	Bett Road 1L05 Reconduct ROW	163,447
108	Build Pine Tree 230/12.47kV Sub	22,441,863
109	Byhalia 230-13.8kV Phase 1 Expand L	201,532
110	Byhalia 230-13.8kV Phase 2 Add 2nd	447,042
111	Camlin XFMR Monitor - Virlilia Sub	261,846
112	Canton 230kV Switch Replacement	438,710
113	Cleveland South: Install circuit sw	1,622,909
114	Cosmos Substation	18,848,271
115	County Line Substation	599,062
116	Crenshaw: Add Circuit Switcher	309,282
117	Deerfield 230kV Sub Land Purchase	101,938
118	Delta Steam Replace Capacitor Bank	469,426
119	Drew: Add circuit switchers, replac	1,099,368
120	Durant: Add circuit switchers, repl	905,846
121	EMI: 13.8kV,2.67MVA Reg (Johns-Mans	411,461
122	EMI: Camlin Pilot (Gerald Andrus)	116,496
123	EMI: Camlin Pilot (Grenada S)	120,222
124	EMI: Camlin Pilot (Lakeover)	687,225
125	EMI: Camlin Pilot (Ray Braswell)	228,532
126	EML: 115-13.8kV \| 20MVA LTC	350,876
127	EML: 230-13.8kV \| 67MVA Incremental	692,868
128	EML: Camlin Mon S Grenada AT1.	124,722
129	EML: Rebuild GA22 Reg(Fannin Rd)	315,398
130	Florence FA01 Reconduct ROW	589,763
131	Freeport: Install Camlin XFMR Moni	346,127
132	Gerald Andrus 230kV DBAPS Intercn	390,870
133	Grenada Industrial 115kV Substation	15,344,077
134	Grenada South Remote End Upgrades	178,260
135	Grenada: Add circuit switchers, rep	910,283
136	Indianola 230: Repl AT1 Tsfr Swi &	172,163
137	Indianola: Replace Control House &	1,788,134
138	Indro Robotics (Lake Castle)	252,034
139	Indro Robotics (Site 3)	252,203
140	Indro Robotics Pilot (Madison)	254,159
141	Leland: Replace breaker 3G05 and ad	534,040
142	Mannsdale 230kV Substation	13,258,525
143	Mantero Substation	12,603,811
144	Midnight: rpl ABS J0348 & Steel Bus	193,295
145	Midnight: rpl Oil Pump on J0346	132,409
146	Oak Bend Substation	3,153,742
147	Pelahatchie: Replace capacitor bank	458,442
148	Pickens 230kV Rplc Ln Panel	284,808
149	Pickens: Replace 4 ea. HV Breakers	1,606,926
150	South Canton 230kV Rplc Ln Panel	392,982
151	Spencer Potash: Replace Main Breake	219,349
152	Tillatoba 115kV Remote End Upgrades	115,877
153	Tillatoba: Replace Breaker J2520 &	263,375
154	Virliila - Bridging Power	598,116
155	Wolf Creek - Add 500kV Breaker	2,737,213
156	OTHER TRANSMISSION & DISTRIBUTION SUBS	1,648,407
157	Bowling Green - Durant 115kV CAP	167,459
158	C6ML300092: Canton - Pickens 230kV	998,801
159	C6ML300111: Grand Gulf to Port Gibs	1,262,297
160	C6ML300119: Onward SS - Redwood SS	131,028
161	C6ML300128: Isola SS - Belzoni 115k	549,982
162	C6ML300134: Jackson/Southwest - Elt	161,227
163	C6ML300135: Elton Rd. - Byram 115kV	544,801
164	C6ML300146: Fernwood - Progress 115	845,188
165	C6ML300150: Salem - Silver Creek 11	1,154,000
166	C6ML300153: Salem - Silver Creek 11	773,727
167	C6ML300158: Tillatoba - Indianola 2	715,749
168	C6ML300159: Isola SS - Belzoni 115k	556,246
169	C6ML300176: Magee - New Hebron 115k	169,576
170	C6ML300190: Franklin - McKnight 500	463,392
171	C6ML300206: Indianola - Tillatoba 2	129,423
172	C6ML300226: Franklin - Ray Braswell	382,007
173	Catlett-Tinnin Rd 230kV Line Cut-In	299,739
174	Church Rd-Getwell 230kV T-Line	21,889,002
175	E. Vicksburg-E. Vicksburg 115kV CAP	144,677
176	Getwell-Twinkletown 230kV Cut-In	1,835,647
177	Greenville TCEPA - Arcola 115kV CAP	280,937
178	Grenada Ind-Grenada S 115kV Cut-In	1,997,713
179	Indianola - Tillatoba 230kV CAP	191,504
180	McComb-CE Norfield 115Kv T-Ln Cutin	115,714
181	Panther Burn-Hollandale UG Fiber	454,200
182	Pelahatchie - Rankin 115kV CAP	203,882
183	S Canton-Pickens 230kV Ln Rebuild	6,045,654
184	Tillatoba-Grenada Ind 115kV Cut-In	2,036,487
185	OTHER TRANSMISSION LINES PLANT	1,033,338
186	UNDISTRIBUTED OVERHEADS:	1,149,069
43	Total	510,924,980

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
Explain in a footnote any important adjustments during year. Explain in a footnote any difference between the amount for book cost of plant retired, Line 12, column (c), and that reported for electric plant in service, page 204, column (d), excluding retirements of non-depreciable property. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No.	Item (a)	Total (c + d + e) (b)	Electric Plant in Service (c)	Electric Plant Held for Future Use (d)	Electric Plant Leased To Others (e)
Section A. Balances and Changes During Year
1	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance Beginning of Year	1,867,952,194	1,867,945,386	6,808
2	Depreciation Provisions for Year, Charged to
3	DepreciationExpenseExcludingAdjustments (403) Depreciation Expense	229,945,326	(a) 229,945,326
4	DepreciationExpenseForAssetRetirementCosts (403.1) Depreciation Expense for Asset Retirement Costs	1,504,443	1,504,443
5	ExpensesOfElectricPlantLeasedToOthers (413) Exp. of Elec. Plt. Leas. to Others
6	TransportationExpensesClearing Transportation Expenses-Clearing
7	OtherClearingAccounts Other Clearing Accounts
8	OtherAccounts Other Accounts (Specify, details in footnote):
9.1	Other Accounts (Specify, details in footnote):	40,228	(b) 40,228
10	DepreciationProvision TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)	231,489,997	231,489,997
11	Net Charges for Plant Retired:
12	BookCostOfRetiredPlant Book Cost of Plant Retired	60,765,784	(c) 60,765,784
13	CostOfRemovalOfPlant Cost of Removal	38,459,874	38,459,874
14	SalvageValueOfRetiredPlant Salvage (Credit)	4,142,602	4,142,602
15	NetChargesForRetiredPlant TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)	95,083,056	95,083,056
16	OtherAdjustmentsToAccumulatedDepreciation Other Debit or Cr. Items (Describe, details in footnote):
17.1	Other Debit or Cr. Items (Describe, details in footnote):	428,772	(d) 428,772
18	BookCostOfAssetRetirementCosts Book Cost or Asset Retirement Costs Retired
19	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)	2,004,787,907	2,004,781,099	6,808
Section B. Balances at End of Year According to Functional Classification
20	AccumulatedDepreciationSteamProduction Steam Production	331,733,813	331,731,428	2,385
21	AccumulatedDepreciationNuclearProduction Nuclear Production
22	AccumulatedDepreciationHydraulicProductionConventional Hydraulic Production-Conventional
23	AccumulatedDepreciationHydraulicProductionPumpedStorage Hydraulic Production-Pumped Storage
24	AccumulatedDepreciationOtherProduction Other Production	412,058,421	412,058,421
25	AccumulatedDepreciationTransmission Transmission	540,668,374	540,663,951	4,423
26	AccumulatedDepreciationDistribution Distribution	648,981,597	648,981,597
27	AccumulatedDepreciationRegionalTransmissionAndMarketOperation Regional Transmission and Market Operation
28	AccumulatedDepreciationGeneral General	71,345,702	71,345,702
29	AccumulatedProvisionForDepreciationOfElectricUtilityPlant TOTAL (Enter Total of lines 20 thru 28)	2,004,787,907	2,004,781,099	6,808

FOOTNOTE DATA

(a) Concept: DepreciationExpenseExcludingAdjustments

Excludes service company depreciation allocations of $4,239,515 (included in the depreciation expense shown on page 336), since these allocations do not offset to accumulated reserves.

(b) Concept: OtherAccounts

Includes depreciation on Gerald Andrus pipelines and Independence, which is accounted for as fuel expense.

(c) Concept: BookCostOfRetiredPlant

Excludes retirements of $1,694,681 (included in Amortization of Other Utility Plant shown on pages 204 - 207), since these retirements do not offset to accumulated depreciation reserves.

(d) Concept: OtherAdjustmentsToAccumulatedDepreciation


Loss on sale of land			$435,246
Gain on sale of land			(6,474)
Total			$428,772

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
Report below investments in Account 123.1, Investments in Subsidiary Companies. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f). Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No.	DescriptionOfInvestmentsInSubsidiaryCompanies Description of Investment (a)	DateOfAcquisitionInvestmentsInSubsidiaryCompanies Date Acquired (b)	DateOfMaturityInvestmentsInSubsidiaryCompanies Date of Maturity (c)	InvestmentInSubsidiaryCompanies Amount of Investment at Beginning of Year (d)	EquityInEarningsOfSubsidiaryCompanies Equity in Subsidiary Earnings of Year (e)	InterestAndDividendRevenueFromInvestments Revenues for Year (f)	InvestmentInSubsidiaryCompanies Amount of Investment at End of Year (g)	InvestmentGainLossOnDisplosal Gain or Loss from Investment Disposed of (h)
1	MS Sunflower Partnership, LLC - Subsidiary Company Subheading	06/30/2021
2	MS Sunflower Partnership, LLC - Capital Contribution			105,655,881		1,344,659	107,000,540
3	MS Sunflower Partnership, LLC - Outside Basis			4,400,015	7,319,289		11,719,304
4	MS Sunflower Partnership, LLC - Subtotal			101,255,866	7,319,289	1,344,659	95,281,236
5	Mississippi Power & Light Co. - Subsidiary Company Subheading
6	Mississippi Power & Light Co. - Capital Contribution			1,000			1,000
7	Mississippi Power & Light Co. - Unappropriated Undistributed Subsidiary Earnings			758			758
8	Mississippi Power & Light Co. - Subtotal			242			242
42	Total Cost of Account 123.1 $		Total	101,256,108	7,319,289	1,344,659	95,281,478

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

MATERIALS AND SUPPLIES
For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No.	Account (a)	Balance Beginning of Year (b)	Balance End of Year (c)	Department or Departments which Use Material (d)
1	Fuel Stock (Account 151)	16,188,254	14,948,488
2	Fuel Stock Expenses Undistributed (Account 152)		10,322
3	Residuals and Extracted Products (Account 153)
4	Plant Materials and Operating Supplies (Account 154)
5	Assigned to - Construction (Estimated)	(a) 82,702,416	(b) 92,928,333	Electric
6	Assigned to - Operations and Maintenance
7	Production Plant (Estimated)	5,592,842	11,913,718	Electric
8	Transmission Plant (Estimated)		178,959	Electric
9	Distribution Plant (Estimated)	1,590,200	1,697,865	Electric
10	Regional Transmission and Market Operation Plant (Estimated)
11	Assigned to - Other (provide details in footnote)
12	TOTAL Account 154 (Enter Total of lines 5 thru 11)	89,885,458	106,718,875
13	Merchandise (Account 155)
14	Other Materials and Supplies (Account 156)
15	Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)
16	Stores Expense Undistributed (Account 163)	5,640,795	6,536,867
17
18
19
20	TOTAL Materials and Supplies	111,714,507	128,214,552

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesConstruction


			BALANCE AT
			BEG OF YEAR
Production (estimated)			$34,210,027
Transmission (estimated)			10,713,143
Distribution (estimated)			37,779,246
Total Assigned to Construction (estimated)			$82,702,416

(b) Concept: PlantMaterialsAndOperatingSuppliesConstruction


			BALANCE AT
			END OF YEAR
Production (estimated)			$29,481,500
Transmission (estimated)			17,785,987
Distribution (estimated)			45,660,846
Total Assigned to Construction (estimated)			$92,928,333

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	SO2 Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year	189,580										189,580
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)	15,931		15,930		15,930		15,930		(a) 446,047		509,768	0
5	Returned by EPA
6
7
8	Purchases/Transfers:	75										75
9
10
11
12
13
14
15	Total	75										75
16
17	Relinquished During Year:
18	Charges to Account 509
19	Other:
20	Allowances Used
20.1	Allowances Used
21	Cost of Sales/Transfers:
22	Compliance Deduction	3,440										3,440
23
24
25
26
27
28	Total	3,440										3,440
29	Balance-End of Year	202,146		15,930		15,930		15,930		446,047		695,983
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)
33	Net Sales Proceeds (Other)
34	Gains
35	Losses
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year
37	Add: Withheld by EPA
38	Deduct: Returned by EPA
39	Cost of Sales
40	Balance-End of Year
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)
44	Net Sales Proceeds (Other)
45	Gains
46	Losses

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: AllowancesIssuedLessWithheldAllowancesNumber

Future years include allowances issued from 2028 through 2055.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	NOx Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year	2,809	7,406									2,809	7,406
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)	1,873		1,873		1,873		1,873		3,746		11,238
5	Returned by EPA
6
7
8	Purchases/Transfers:
9	Current Period Adjustment	628										628
10
11
12
13
14
15	Total	628										628
16
17	Relinquished During Year:
18	Charges to Account 509	1,535	2,803									1,535	2,803
19	Other:
20	Allowances Used
20.1	Allowances Used
21	Cost of Sales/Transfers:
22
23
24
25
26
27
28	Total
29	Balance-End of Year	2,519	4,603	1,873		1,873		1,873		3,746		11,884	4,603
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)
33	Net Sales Proceeds (Other)
34	Gains
35	Losses
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year
37	Add: Withheld by EPA
38	Deduct: Returned by EPA
39	Cost of Sales
40	Balance-End of Year
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)
44	Net Sales Proceeds (Other)
45	Gains
46	Losses

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfExtraordinaryPropertyLoss Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).] (a)	ExtraordinaryPropertyLossesNotYetRecognized Total Amount of Loss (b)	ExtraordinaryPropertyLossesRecognized Losses Recognized During Year (c)	ExtraordinaryPropertyLossesWrittenOffAccountCharged Account Charged (d)	ExtraordinaryPropertyLossesWrittenOff Amount (e)	ExtraordinaryPropertyLosses Balance at End of Year (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
20	TOTAL

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)] (a)	UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized Total Amount of Charges (b)	UnrecoveredPlantAndRegulatoryStudyCostsRecognized Costs Recognized During Year (c)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged Account Charged (d)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff Amount (e)	UnrecoveredPlantAndRegulatoryStudyCosts Balance at End of Year (f)
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49	TOTAL

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

Transmission Service and Generation Interconnection Study Costs
Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies. List each study separately. In column (a) provide the name of the study. In column (b) report the cost incurred to perform the study at the end of period. In column (c) report the account charged with the cost of the study. In column (d) report the amounts received for reimbursement of the study costs at end of period. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.	DescriptionOfStudyPerformed Description (a)	StudyCostsIncurred Costs Incurred During Period (b)	StudyCostsAccountCharged Account Charged (c)	StudyCostsReimbursements Reimbursements Received During the Period (d)	StudyCostsAccountReimbursed Account Credited With Reimbursement (e)
1	Transmission Studies
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20	Total
21	Generation Studies
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39	Total
40	Grand Total

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

OTHER REGULATORY ASSETS (Account 182.3)
Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Assets being amortized, show period of amortization.
				CREDITS
Line No.	DescriptionAndPurposeOfOtherRegulatoryAssets Description and Purpose of Other Regulatory Assets (a)	OtherRegulatoryAssets Balance at Beginning of Current Quarter/Year (b)	IncreaseDecreaseInOtherRegulatoryAssets Debits (c)	OtherRegulatoryAssetsWrittenOffAccountCharged Written off During Quarter/Year Account Charged (d)	OtherRegulatoryAssetsWrittenOffRecovered Written off During the Period Amount (e)	OtherRegulatoryAssets Balance at end of Current Quarter/Year (f)
1	Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 128 months beg July 2022	3,654,803		926	356,566	3,298,237
2	Asset Retirement Obligation - Sunflower		369,344			369,344
3	Asset Retirement Obligation - Fossil	6,009,856	1,754,321			7,764,177
4	Asset Retirement Obligation - Coal	765,985	484,724			1,250,709
5	Defined Benefit Pension & Other Post Retirement Plans	108,441,240		190, 107, 283, 410.1, 411.1, 926, 253	15,795,849	92,645,391
6	Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 130 months beg Oct 2020	1,454,487		926	191,799	1,262,688
7	Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 120 months beg July 2021	9,471,087		926	1,262,812	8,208,275
8	Deferred Attorney General Litigation Costs MPSC Docket No. 2009-UN-388 Amort 6 years beg April 2020	10,858,605		506, 561.5, 920, 921, 923, 926, 928	4,826,046	6,032,559
9	Energy Efficiency Rider Under-Recovery	35,972,051	6,843,276			42,815,327
10	Restructuring Credit Rider Under-Recovery MPSC Docket No. 2018-UA-39	910,517		407.3	62,319	848,198
11	Ad Valorem Tax Adjustment Rider MPSC Docket No. 2014-UN-132	39,880,809		408.1	101,934	39,778,875
12	Unit Power Cost Recovery Rider Under-Recovery MPSC Docket No. 2014-UN-132	16,425,471		407.3	8,480,069	7,945,402
13	COVID-19 Bad Debt Expense MPSC Docket No. 2018-AD-141 and MPSC Docket No. 2018-UN-205	9,849,236		904	2,188,719	7,660,517
14	Income Taxes	30,066,034	1,690,057			31,756,091
15	Formula Rate Plan Revenue Increase MPSC Docket No. 2018-UN-205	9,169,634		407.3	9,169,634
16	Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 138 months beg Oct 2022	7,093,272		926	773,811	6,319,461
17	Derivative Instruments and Hedging Activities	10,145,279		244	10,145,279
18	MISO Financial Transmission Rights Mark-to-Market		2,245,131			2,245,131
19	Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 135 months beg April 2023	6,174,038		926	588,003	5,586,035
20	Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 139 months beg April 2023	4,160,324		926	384,030	3,776,294
21	Power Management Rider Under-Recovery MPSC Docket No. 2014-UN-132	66,205,276		407.3, 431	20,642,381	45,562,895
22	Grid Modernization Rider Under-Recovery MPSC Docket No. 2017-UN-198	2,087,335	13,479,089			15,566,424
23	MISO Rider Under-Recovery MPSC Docket No. 2014-UN-132	7,743,585		407.3	7,017,801	725,784
24	Formula Rate Plan Revenue Increase MPSC Docket No. 2023-UN-142 - Amort July 2024-Mar 2025		7,262,927	407.3	4,841,951	2,420,976
25	Qualified Pension Settlement Cost Deferral MPSC Docket No. 2020-UA-91 Amort 276 months beg July 2024		621,427	926	13,381	608,046
26	Vegetation Management Reserve Rider -MPSC Docket No. 2012-UN-424	5,464,532	9,893,694	407.3	5,464,532	9,893,694
44	TOTAL	392,003,456	44,643,990		92,306,916	344,340,530

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

MISCELLANEOUS DEFFERED DEBITS (Account 186)
Report below the particulars (details) called for concerning miscellaneous deferred debits. For any deferred debit being amortized, show period of amortization in column (a) Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
				CREDITS
Line No.	Description of Miscellaneous Deferred Debits (a)	Balance at Beginning of Year (b)	Debits (c)	Credits Account Charged (d)	Credits Amount (e)	Balance at End of Year (f)
1	Other Post Retirement Benefits		50,953,538			50,953,538
2	Non-Expense Accrued Labor	2,650,632	519,371			3,170,003
3	Other	39,604		131	34,004	5,600
47	Miscellaneous Work in Progress
48	Deferred Regulatory Comm. Expenses (See pages 350 - 351)
49	TOTAL	2,690,236				54,129,141

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

ACCUMULATED DEFERRED INCOME TAXES (Account 190)
Report the information called for below concerning the respondent’s accounting for deferred income taxes. At Other (Specify), include deferrals relating to other income and deductions.
Line No.	DescriptionOfAccumulatedDeferredIncomeTax Description and Location (a)	AccumulatedDeferredIncomeTaxes Balance at Beginning of Year (b)	AccumulatedDeferredIncomeTaxes Balance at End of Year (c)
1	Electric
2	(a) See Footnote	53,598,274	46,220,577
7	Other
8	TOTAL Electric (Enter Total of lines 2 thru 7)	53,598,274	46,220,577
9	Gas
15	Other
16	TOTAL Gas (Enter Total of lines 10 thru 15)
17.1	Other (Specify)
17	Other (Specify)
18	TOTAL (Acct 190) (Total of lines 8, 16 and 17)	53,598,274	46,220,577

Notes

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: DescriptionOfAccumulatedDeferredIncomeTax


	BALANCE AT BEG OF YEAR	BALANCE AT END OF YEAR
Abandonment Loss	$1,425,680	$1,425,680
Intrst/Tax Tax Deficiencies	424,150	424,150
Taxable Unbilled Revenue	6,193,525	1,273,775
Property Insurance Reserve	7,733,496	10,240,650
Capitalized Repairs	140,094	46,946
Injuries & Damages Reserve	1,086,835	1,534,718
Contribution in Aid of Construction	15,459,815	20,683,942
Pension Plan	(24,857,456)	(26,631,334)
Defined Benefit Pension	23,955,638	19,352,295
Supplemental Pension Plan	515,447	567,212
Other Post Employment Benefits	(10,645,600)	(9,727,912)
Deferred Fuel	(20,616,346)	(13,350,320)
Removal Cost	(34,139,704)	(36,961,561)
Accrual of Reserves	1,303	—
Asset Retirement Obligation	1,006	1,006
Litigation Settlement	—	1,087,032
Accrued Medical Claims	581,416	739,116
Uncollectible Accounts	826,278	541,996
Def Gain/Basis Step-Up	174,266	156,850
Basis Step-Up	2,658,853	2,430,107
Partnership Income/Loss	(35,428)	(796,618)
Contract Deferred Revenue	27,900	220,759
Lease - Rental Expense	165,353	203,738
Environmental Reserve	998	(2,467,479)
Incentive Compensation	2,292,396	2,813,310
Long-Term Incentive Compensation	114,512	132,161
Stock Options	51,231	73,326
Restricted Stock Awards	161,583	175,245
Deferred Directors's Fees	—	83,205
Deferred Compensation	1,029,188	—
Income Tax Adjustment	58,031,426	56,400,407
Tax Attribute - NOL/CR Carryforward	2,662,843	2,581,153
ADIT-Tax CR Carryforward - Fed	5,116,423	6,118,634
ADIT - Tax CR Carryforward - St	7,999,247	8,360,510
Fed Offset-St Carryover	(2,866,871)	(1,817,137)
ADIT NOL Carryforward - Fed	2,263,777	—
ADIT NOL Carryforward - St	5,665,000	305,015
TOTAL	$53,598,274	$46,220,577

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

CAPITAL STOCKS (Account 201 and 204)
Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No.	Class and Series of Stock and Name of Stock Series (a)	Number of Shares Authorized by Charter (b)	Par or Stated Value per Share (c)	Call Price at End of Year (d)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares (e)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount (f)	Held by Respondent As Reacquired Stock (Acct 217) Shares (g)	Held by Respondent As Reacquired Stock (Acct 217) Cost (h)	Held by Respondent In Sinking and Other Funds Shares (i)	Held by Respondent In Sinking and Other Funds Amount (j)
1	Common Stock (Account 201)
2
3
4
5	Total
6	Preferred Stock (Account 204)
7
8
9
10	Total

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2025-04-15

Year/Period of Report

End of:

2024

/

Q4

Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No.	Item (a)	Amount (b)
1	DonationsReceivedFromStockholdersAbstract Donations Received from Stockholders (Account 208)
2	DonationsReceivedFromStockholders Beginning Balance Amount
3.1	IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders Increases (Decreases) from Sales of Donations Received from Stockholders
4	DonationsReceivedFromStockholders Ending Balance Amount
5	ReductionInParOrStatedValueOfCapitalStockAbstract Reduction in Par or Stated Value of Capital Stock (Account 209)
6	ReductionInParOrStatedValueOfCapitalStock Beginning Balance Amount
7.1	IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8	ReductionInParOrStatedValueOfCapitalStock Ending Balance Amount
9	GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10	GainOnResaleOrCancellationOfReacquiredCapitalStock Beginning Balance Amount
11.1	IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock
12	GainOnResaleOrCancellationOfReacquiredCapitalStock Ending Balance Amount
13	MiscellaneousPaidInCapitalAbstract Miscellaneous Paid-In Capital (Account 211)
14	MiscellaneousPaidInCapital Beginning Balance Amount	329,266,361
15.1	IncreasesDecreasesDueToMiscellaneousPaidInCapital Increases (Decreases) Due to Miscellaneous Paid-In Capital
16	MiscellaneousPaidInCapital Ending Balance Amount	329,266,361
17	OtherPaidInCapitalAbstract Other Paid in Capital
18	OtherPaidInCapitalDetail Beginning Balance Amount
19.1	IncreasesDecreasesInOtherPaidInCapital Increases (Decreases) in Other Paid-In Capital
20	OtherPaidInCapitalDetail Ending Balance Amount
40	OtherPaidInCapital Total	329,266,361

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

CAPITAL STOCK EXPENSE (Account 214)
Report the balance at end of the year of discount on capital stock for each class and series of capital stock. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No.	NameOfClassAndSeriesOfStock Class and Series of Stock (a)	CapitalStockExpense Balance at End of Year (b)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22	TOTAL

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

LONG-TERM DEBT (Account 221, 222, 223 and 224)
Report by Balance Sheet Account the details concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds, and in column (b) include the related account number. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received, and in column (b) include the related account number. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued, and in column (b) include the related account number. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (m). Explain in a footnote any difference between the total of column (m) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No.	ClassAndSeriesOfObligationCouponRateDescription Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates) (a)	RelatedAccountNumber Related Account Number (b)	Principal Amount of Debt Issued (c)	LongTermDebtIssuanceExpensePremiumOrDiscount Total Expense, Premium or Discount (d)	LongTermDebtIssuanceExpenses Total Expense (e)	LongTermDebtPremium Total Premium (f)	LongTermDebtDiscount Total Discount (g)	NominalDateOfIssue Nominal Date of Issue (h)	DateOfMaturity Date of Maturity (i)	AmortizationPeriodStartDate AMORTIZATION PERIOD Date From (j)	AmortizationPeriodEndDate AMORTIZATION PERIOD Date To (k)	Outstanding (Total amount outstanding without reduction for amounts held by respondent) (l)	Interest for Year Amount (m)
1	Bonds (Account 221)
2	3.75% Series	221	100,000,000		954,738		30,000	03/21/2014	07/01/2024	03/21/2014	07/01/2024	(a) 0	1,833,333
3	2.85% Series	221	375,000,000		2,878,733		120,000	05/13/2016	06/01/2028	05/13/2016	06/01/2028	375,000,000	10,687,500
4	4.9% Series	221	260,000,000		8,107,303			09/15/2016	10/01/2066	09/15/2016	10/01/2066	260,000,000	12,740,000
5	3.25% Series	221	150,000,000		1,362,173		511,500	11/14/2017	12/01/2027	11/14/2017	12/01/2027	150,000,000	4,875,000
6	4.52% Series	221	55,000,000		511,787			12/12/2018	12/01/2038	12/12/2018	12/01/2038	55,000,000	2,486,000
7	3.85% Series 1	221	300,000,000		3,171,620		3,891,000	06/05/2019	06/01/2049	06/05/2019	06/01/2049	300,000,000	11,550,000
8	3.85% Series 2	221	135,000,000		1,395,028	10,813,500		11/19/2019	06/01/2049	11/19/2019	06/01/2049	135,000,000	5,197,500
9	3.5% Series 1	221	170,000,000		2,166,734		2,410,600	05/22/2020	06/01/2051	05/22/2020	06/01/2051	170,000,000	5,950,000
10	3.5% Series 2	221	200,000,000		2,150,279	2,754,000		03/12/2021	06/01/2051	03/12/2021	06/01/2051	200,000,000	7,000,000
11	2.55% Series	221	200,000,000		1,783,526		516,000	11/16/2021	12/01/2033	11/16/2021	12/01/2033	200,000,000	5,100,000
12	5.0% Series	221	300,000,000		2,781,397		171,000	05/12/2023	09/01/2033	05/12/2023	09/01/2033	300,000,000	15,000,000
13	5.85% Series	221	300,000,000		3,363,055		138,000	05/16/2024	06/01/2054	05/16/2024	06/01/2054	300,000,000	10,968,750
14	Subtotal		2,545,000,000		30,626,373	13,567,500	7,788,100					2,445,000,000	93,388,083
15	Reacquired Bonds (Account 222)
16
17
18
19	Subtotal
20	Advances from Associated Companies (Account 223)
21
22
23
24	Subtotal
25	Other Long Term Debt (Account 224)
26	Revolving Credit Facility	224											2,767,651
27	Subtotal												2,767,651
33	TOTAL		2,545,000,000									2,445,000,000	(b) 96,155,734

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: Bonds

Mortgage Bond 3.75% series was redeemed on June 27, 2024. The unamortized debt expense of $1,038 and unamortized debt discount of $32 has been moved to the account 189, Unamortized Loss on Reacquired Debt, and will be amortized over the remaining life ending July 1, 2024.

(b) Concept: InterestExpenseOnLongTermDebtIssued

Total interest for Accounts 221 and 224 is recorded in Account 427, as shown on page 117, line 62.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No.	Particulars (Details) (a)	Amount (b)
1	Net Income for the Year (Page 117)	255,834,808
2	Reconciling Items for the Year
3
4	Taxable Income Not Reported on Books
5	(a) See Footnote Detail	14,527,472
9	Deductions Recorded on Books Not Deducted for Return
10	(b) See Footnote Detail	5,850,042
14	Income Recorded on Books Not Included in Return
15	(c) See Footnote Detail	1,125,018
19	Deductions on Return Not Charged Against Book Income
20	(d) See Footnote Detail	105,077,628
21	(e) Other Reconciling Items - See footnote detail	52,731,656
27	Federal Tax Net Income	193,686,388
28	Show Computation of Tax:
29	Normal and Surtax @ 21%	40,674,141
30	(f) Estimated Consolidated Income Tax Allocated - See Footnote Detail

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: TaxableIncomeNotReportedOnBooksDescription


Taxable Income Not Recorded on Books:
Avoided Cost - Tax Interest			$4,303,708
Deferred Contract Revenue			887,258
Unbilled Revenue			(19,718,438)
Total			($14,527,472)

(b) Concept: DeductionsRecordedOnBooksNotDeductedForReturnDescription


Deductions Recorded on Books Not Deducted for Return:
Accrual of Reserves			$6,301,762
Deferred Compensation and Benefits			(309,836)
Meals and Entertainment			155,651
Penalties			89,116
Political Expenses			752,757
Reserve for Uncollectible Accounts			(1,139,408)
Total			$5,850,042

(c) Concept: IncomeRecordedOnBooksNotIncludedInReturnDescription


Income Recorded on Books Not Included in Return:
Allowance for Funds Used During Construction			$8,283,767
Equity Earnings in Subs			(7,319,289)
Tax Equity Partnership			160,540
Total			$1,125,018

(d) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription


Deductions on Return Not Charged Against Book Income:
Amortization of Other Assets			($17,866,588)
Amortization of Regulatory Assets			(2,188,719)
Bond Reacquisition Loss			(888,375)
Deferred Compensation & Benefits			101,982
Deferred Fuel			(15,643,361)
Depreciation of Plant Assets			155,797,666
Service Company Billings			(451,155)
Pension and OPEB			2,503,511
Prepaid Expenses			(9,263)
Research and Development Costs			(5,463,753)
Software Costs			772,115
UOP Repairs			(11,586,432)
Total			$105,077,628

(e) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription


Reconciling Items for the Year:
Net Operating Loss			($25,472,000)
Federal Income Tax Accrual - Current year			40,674,141
Federal Income Tax Accrual - Prior year			(1,994,502)
Investment Tax Credit			(379,910)
FIN 48 taxes			1,177,094
Provision for Deferred Income Tax			38,432,344
State Income Tax - Current Year			(2,112,216)
State Income Tax Accrual - Prior Year			2,406,705
Total			$52,731,656

(f) Concept: ComputationOfTaxDescription

The Respondent intends to join in the filing of a consolidated Federal Income Tax Return by Entergy Corporation and Subsidiary Companies for the year ended 2024. The estimated consolidated tax allocable under Entergy and Subsidiary Companies Intercompany Income Tax Allocation Agreement based on the provisions of Securities and Exchange Commission Rule 45(c) follows:


FOOTNOTE DATA


Entergy Utility Property, Inc.			$515,000
Entergy Utility Affiliates, LLC			(14,000)
Entergy Utility Assets Holdings, Inc.			2,733,000
Entergy Utility Enterprises, Inc.			1,000
Entergy Utility Group, Inc.			(403,000)
System Energy Resources, Inc.			(3,992,000)
Entergy Operations, Inc.			(149,000)
Entergy Corporation			(94,040,000)
Entergy Nuclear New York Investment Company, LLC			3,000
Entergy Nuclear Holding Company #3, LLC			(4,058,000)
Entergy Assets Management Company, LLC			(3,550,000)
Entergy Northeast Holdings, LLC			(10,801,000)
Entergy Power Marketing Holding II, Inc.			(102,000)
Entergy Nuclear Power Marketing, LLC			2,108,000
Entergy Nuclear, Inc.			(309,000)
Entergy Nuclear Holding Company #1			(4,877,000)
Entergy Nuclear Operations, Inc.			(11,687,000)
Entergy Power Holdings, Inc.			9,427,000
Entergy TransCo HoldCo, LLC			(7,000)
EAM Nelson Holding, LLC			351,000
Entergy Power Investment Holding, Inc.			10,507,000
Entergy Mississippi Turbine Company			(385,000)
Entergy Power, LLC			(255,000)
Entergy Enterprises, Inc.			(34,000)
Entergy Power Gas Operations, LLC			28,913,000
Entergy Power Marketing Holding I, Inc.			(9,068,000)
Entergy Nuclear Palisades, LLC			(9,581,000)
Entergy Utility Affiliates Holdings, Inc.			1,000
EWO Marketing, LLC			(1,978,000)
Entergy Global, LLC			2,175,000
Entergy Ventures, Inc.			(152,000)
EUP Holdings, LLC			520,000
Entergy Assets Management Holding, Inc.			(196,000)
Entergy Technology Company			(21,000)
Entergy TransCo Texas, LLC			(11,000)
Entergy Services Holding, Inc.			(6,497,000)
Entergy Asset Management, Inc.			9,800,000
Entergy Nuclear Indian Point 2, LLC			(12,517,000)
Entergy Nuclear Indian Point 3, LLC			(11,827,000)
Entergy Finance Company, LLC			156,694,000
Entergy New Orleans, LLC			(398,000)
Entergy Utility Holding Company, LLC			(36,839,000)
Total			$—


FOOTNOTE DATA


Supplemental Information -Entergy Utility Holding Company, LLC
Entergy Louisiana, LLC			($67,923,000)
Entergy Arkansas, LLC			(8,458,000.00)
Entergy Mississippi, LLC			39,542,000.00
Total			($36,839,000)

Supplemental Information -Entergy Services Holdings, Inc
Entergy Services Holdings, Inc.			($3,423,000)
Entergy Services, LLC			(1,811,000.00)
Entergy Account Services, LLC			(1,263,000.00)
Total			($6,497,000)

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (d). Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (l) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
					BALANCE AT BEGINNING OF YEAR					BALANCE AT END OF YEAR		DISTRIBUTION OF TAXES CHARGED
Line No.	DescriptionOfTaxesAccruedPrepaidAndCharged Kind of Tax (See Instruction 5) (a)	TypeOfTax Type of Tax (b)	TaxJurisdiction State (c)	TaxYear Tax Year (d)	TaxesAccrued Taxes Accrued (Account 236) (e)	PrepaidTaxes Prepaid Taxes (Include in Account 165) (f)	TaxesCharged Taxes Charged During Year (g)	TaxesPaid Taxes Paid During Year (h)	TaxAdjustments Adjustments (i)	TaxesAccrued Taxes Accrued (Account 236) (j)	PrepaidTaxes Prepaid Taxes (Included in Account 165) (k)	TaxesAccruedPrepaidAndCharged Electric (Account 408.1, 409.1) (l)	IncomeTaxesExtraordinaryItems Extraordinary Items (Account 409.3) (m)	AdjustmentsToRetainedEarnings Adjustment to Ret. Earnings (Account 439) (n)	TaxesIncurredOther Other (o)
1	Federal Income Tax	Federal Tax			25,850,388	0	41,384,444	19,045,000		34,579,056		41,437,443			52,999
2	FICA	Federal Tax			912,198	0	7,917,429	7,768,779		1,060,848		3,473,606			4,443,823
3	Federal Uemployment Tax	Federal Tax			1,154	0	36,624	36,268		1,510		16,044			20,580
4	Federal Excise Tax	Federal Tax			0	0				0		21,574			21,574
5	Subtotal Federal Tax				24,937,036	0	49,338,497	11,239,953	0	35,641,414	0	44,948,667	0	0	4,389,830
6	State Income Tax	State Tax			5,835,964	0	3,067,867	4,874,818		4,029,013		3,081,149			13,282
7					0	0				0					0
8	Subtotal State Tax				5,835,964	0	3,067,867	4,874,818	0	4,029,013	0	3,081,149	0	0	13,282
9	Franchise - City	Local Tax			5,555,865	0	18,430,733	19,087,781		4,898,817		18,430,732			1
10	Subtotal Local Tax				5,555,865	0	18,430,733	19,087,781	0	4,898,817	0	18,430,732	0	0	1
11	Privilege License	Other Taxes			0	62,623	78,299	74,662		0	58,986	78,299			0
12	Regulatory Commission	Other Taxes			0	0	2,928,259	2,928,259		0		2,928,259			0
13	Subtotal Other Tax				0	62,623	3,006,558	3,002,921	0	0	58,986	3,006,558	0	0	0
14	Subtotal Property Tax				0	0	0	0	0	0	0	0	0	0	0
15	Subtotal Real Estate Tax				0	0	0	0	0	0	0	0	0	0	0
16	State Unemployment Tax	Unemployment Tax			1,146	0	38,632	38,190		1,588		16,020			22,612
17	Subtotal Unemployment Tax				1,146	0	38,632	38,190	0	1,588	0	16,020	0	0	22,612
18	State Use Tax	Sales And Use Tax			815,487	0	11,911,816	11,445,055		1,282,248					11,911,816
19	Subtotal Sales And Use Tax				815,487	0	11,911,816	11,445,055	0	1,282,248	0	0	0	0	11,911,816
20	Entergy Services, LLC	Income Tax			0	0				0		3,288,873			3,288,873
21	Subtotal Income Tax				0	0	0	0	0	0	0	3,288,873	0	0	3,288,873
22	State Excise Tax	Excise Tax			0	0				0		21,603			21,603
23	Subtotal Excise Tax				0	0	0	0	0	0	0	21,603	0	0	21,603
24	Subtotal Fuel Tax				0	0	0	0	0	0	0	0	0	0	0
25	Subtotal Federal Insurance Tax				0	0	0	0	0	0	0	0	0	0	0
26	Corporate Franchise Tax-MS	Franchise Tax			2	0	4,755,271	4,755,269		0		4,337,271			418,000
27	Corporate Franchise Tax-AR	Franchise Tax			1	18		1		0	18	150			150
28	Subtotal Franchise Tax				1	18	4,755,271	4,755,270	0	0	18	4,337,421	0	0	417,850
29	Non Income Tax	Miscellaneous Other Tax			1,700,000	0				1,700,000					0
30	Subtotal Miscellaneous Other Tax				1,700,000	0	0	0	0	1,700,000	0	0	0	0	0
31	Subtotal Other Federal Tax				0	0	0	0	0	0	0	0	0	0	0
32	Receipts & Sales	Other State Tax			6,645	0	24,996	30,248		1,393		24,996			0
33	Subtotal Other State Tax				6,645	0	24,996	30,248	0	1,393	0	24,996	0	0	0
34	Subtotal Other Property Tax				0	0	0	0	0	0	0	0	0	0	0
35	Subtotal Other Use Tax				0	0	0	0	0	0	0	0	0	0	0
36	Ad Valorem Tax - MS	Other Ad Valorem Tax			123,662,107	0	131,087,690	121,601,971		133,147,826		126,183,021			4,904,669
37	Ad Valorem Tax - AR	Other Ad Valorem Tax			1,269,092	0	1,320,262	1,295,568		1,293,786		1,320,262			0
38	Subtotal Other Advalorem Tax				124,931,199	0	132,407,952	122,897,539	0	134,441,612	0	127,503,283	0	0	4,904,669
39	Subtotal Other License And Fees Tax				0	0	0	0	0	0	0	0	0	0	0
40	Subtotal Payroll Tax				0	0	0	0	0	0	0	0	0	0	0
41	Subtotal Advalorem Tax				0	0	0	0	0	0	0	0	0	0	0
42	Entergy Services, LLC	Other Allocated Tax			0	0				0		4,070,647			4,070,647
43	Subtotal Other Allocated Tax				0	0	0	0	0	0	0	4,070,647	0	0	4,070,647
44	Subtotal Severance Tax				0	0	0	0	0	0	0	0	0	0	0
45	Subtotal Penalty Tax				0	0	0	0	0	0	0	0	0	0	0
46	Subtotal Other Taxes And Fees				0	0	0	0	0	0	0	0	0	0	0
40	TOTAL				113,909,268	62,641	222,982,322	154,891,869	0	181,996,085	59,004	202,152,203	0	0	20,830,119

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)
Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.
			Deferred for Year		Allocations to Current Year's Income
Line No.	Account Subdivisions (a)	Balance at Beginning of Year (b)	Account No. (c)	Amount (d)	Account No. (e)	Amount (f)	Adjustments (g)	Balance at End of Year (h)	Average Period of Allocation to Income (i)	ADJUSTMENT EXPLANATION (j)
1	Electric Utility
2	3%
3	4%
4	7%
5	10%	4,566,036			411.4	266,633		4,299,403	(a) 20.5 years
8	TOTAL Electric (Enter Total of lines 2 thru 7)	4,566,036				266,633		4,299,403
9	Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10										`
11	Mississippi ITC	9,244,472	411.4	285,398	411.4	382,807		9,147,063	(b) 10 years
47	OTHER TOTAL	9,244,472		285,398		382,807		9,147,063
48	GRAND TOTAL	13,810,508		285,398		649,440		13,446,466

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: AccumulatedDeferredInvestmentTaxCreditsAveragePeriodOfAllocationToIncome

Average lives are based on estimated composite useful lives of the properties and are subject to reconsideration each year.

(b) Concept: AccumulatedDeferredInvestmentTaxCreditsAveragePeriodOfAllocationToIncome

Average lives are based on estimated composite useful lives of the properties and are subject to reconsideration each year.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

OTHER DEFERRED CREDITS (Account 253)
Report below the particulars (details) called for concerning other deferred credits. For any deferred credit being amortized, show the period of amortization. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
			DEBITS
Line No.	Description and Other Deferred Credits (a)	Balance at Beginning of Year (b)	Contra Account (c)	Amount (d)	Credits (e)	Balance at End of Year (f)
1	Long-Term Incentive Plan	458,963	131	208,217	278,955	529,701
2	Non-Qualified Pension funded status	2,894,300	131	118,941	371,632	3,146,991
3	Qualified Pension funded status - See Note 11 - Retirement, Other Postretirement Benefits, and Defined Contribution Plans	15,682,073	182.3, 131, 107, 926	27,068,859		11,386,786
4	Liberty Development	285,000	107, 131, 506	285,000
5	Electric Line Justification Extension	233,900				233,900
6	Miscellaneous non-operating reserve				4,356,840	4,356,840
7	Captive Deposit Program				879,774	879,774
8	Restricted Units Program				333,486	333,486
47	TOTAL	19,554,236		27,681,017	6,220,687	1,906,094

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)

Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property.
For other (Specify),include deferrals relating to other income and deductions.
Use footnotes as required.

CHANGES DURING YEAR

ADJUSTMENTS

Debits

Credits

Line No.

Account

(a)

Balance at Beginning of Year

(b)

Amounts Debited to Account 410.1

(c)

Amounts Credited to Account 411.1

(d)

Amounts Debited to Account 410.2

(e)

Amounts Credited to Account 411.2

(f)

Account Credited

(g)

Amount

(h)

Account Debited

(i)

Amount

(j)

Balance at End of Year

(k)

1

Accelerated Amortization (Account 281)

2

Electric

3

Defense Facilities

4

Pollution Control Facilities

5

Other

5.1

Other (provide details in footnote):

8

TOTAL Electric (Enter Total of lines 3 thru 7)

9

Gas

10

Defense Facilities

11

Pollution Control Facilities

12

Other

12.1

Other (provide details in footnote):

15

TOTAL Gas (Enter Total of lines 10 thru 14)

16

Other

16.1

Other

16.2

Other

17

TOTAL (Acct 281) (Total of 8, 15 and 16)

18

Classification of TOTAL

19

Federal Income Tax

20

State Income Tax

21

Local Income Tax

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization. For other (Specify),include deferrals relating to other income and deductions. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 282
2	Electric	800,329,215	113,585,645	76,095,786			182.3/254	7,058,179	182.3/254	12,868,657	843,629,552
3	Gas
4	Other (Specify)
5	Total (Total of lines 2 thru 4)	800,329,215	113,585,645	76,095,786				7,058,179		12,868,657	843,629,552
6
7
8
9	TOTAL Account 282 (Total of Lines 5 thru 8)	800,329,215	113,585,645	76,095,786				7,058,179		12,868,657	843,629,552
10	Classification of TOTAL
11	Federal Income Tax	651,751,029	89,958,927	62,414,251			182.3/254	6,275,265	182.3/254	11,831,240	684,851,680
12	State Income Tax	148,578,186	23,626,718	13,681,535			182.3/254	782,914	182.3/254	1,037,417	158,777,872
13	Local Income Tax

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283. For other (Specify),include deferrals relating to other income and deductions. Provide in the space below explanations for Page 276. Include amounts relating to insignificant items listed under Other. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 283
2	Electric
3	(a) See Footnote Detail	68,874,234	8,595,739	12,016,807			182.3/190/254	6,308,670	182.3/190/254	2,126,995	61,271,491
9	TOTAL Electric (Total of lines 3 thru 8)	68,874,234	8,595,739	12,016,807				6,308,670		2,126,995	61,271,491
10	Gas
11
12
13
14
15
16
17	TOTAL Gas (Total of lines 11 thru 16)
18	TOTAL Other
19	TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)	68,874,234	8,595,739	12,016,807				6,308,670		2,126,995	61,271,491
20	Classification of TOTAL
21	Federal Income Tax	55,446,533	7,035,440	9,971,293			182.3/190/254	5,110,028	182.3/190/254	1,766,364	49,167,016
22	State Income Tax	13,427,701	1,560,299	2,045,514			182.3/190/254	1,198,642	182.3/190/254	360,631	12,104,475
23	Local Income Tax
NOTES

FOOTNOTE DATA

(a) Concept: DescriptionOfAccumulatedDeferredIncomeTaxOther


	CHANGES DURING YEAR
	BALANCE AT BEGINNING OF YEAR	AMOUNTS DEBITED TO ACCT. 410.1	AMOUNTS CREDITED TO ACCT. 411.1	AMOUNTS DEBITED TO ACCT. 410.2	AMOUNTS CREDITED TO ACCT. 411.2
Deferred Fuel	$520,801	$3,709,954	$346,921	$—	$—
Reg Asset Covid 19	2,457,384	22,982	569,067	—	—
Reg Asset-Securitization	30,061,017	1,686,538	6,144,252	—	—
Prepaid Expenses	621,167	3,103,037	3,393,893	—	—
Minimum Pension Liability	23,955,613	—	—	—	—
Bond Reacquisition Loss	2,488,953	9,328	230,979	—	—
Capitalized Costs	1,267,795	63,900	1,331,695	—	—
Income Tax Adjustment	7,501,504	—	—	—	—
TOTAL	$68,874,234	$8,595,739	$12,016,807	$—	$—


	ADJUSTMENTS
	DEBITS		CREDITS
	ACCOUNT CREDITED	AMOUNT	ACCOUNT DEBITED	AMOUNT	BALANCE AT END OF YEAR
Deferred Fuel		$—		$—	$3,883,834
Reg Asset Covid 19		—		—	1,911,299
Reg Asset-Securitization		—		—	25,603,303
Prepaid Expenses		—		—	330,311
Minimum Pension Liability	190	5,079,657	190	476,314	19,352,270
Bond Reacquisition Loss		—		—	2,267,302
Capitalized Costs		—		—	—
Income Tax Adjustment	182.3/254	1,229,013	182.3/254	1,650,681	7,923,172
TOTAL		$6,308,670		$2,126,995	$61,271,491

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

OTHER REGULATORY LIABILITIES (Account 254)
Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Liabilities being amortized, show period of amortization.
			DEBITS
Line No.	Description and Purpose of Other Regulatory Liabilities (a)	Balance at Beginning of Current Quarter/Year (b)	Account Credited (c)	Amount (d)	Credits (e)	Balance at End of Current Quarter/Year (f)
1	Income Taxes	218,780,373	190, 282,283	6,173,109		212,607,264
2	MISO Financial Transmission Rights Mark-to-Market	799,807	175	799,807
3	Electric Deferred Fuel Over-Recovery	130,645,129	557	4,329,265		126,315,864
4	Gas Hedge Plan Mark-to-Market				1,550,310	1,550,310
5	Formula Rate Plan Lookback True Up MPSC Docket No. 2022-UN-137 - Amort 12 months effective 7/23	582,912	407.4	582,912
6	Grand Gulf Over-Recovery MPSC Docket No. 1984-UN-4620	1,793,164			10,435,796	12,228,960
7	Other Postretirement Plans	7,496,396			10,402,217	17,898,613
41	TOTAL	360,097,781		11,885,093	22,388,323	370,601,011

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

Electric Operating Revenues
The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages. Report below operating revenues for each prescribed account, and manufactured gas revenues in total. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.) See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.	Title of Account (a)	Operating Revenues Year to Date Quarterly/Annual (b)	Operating Revenues Previous year (no Quarterly) (c)	MEGAWATT HOURS SOLD Year to Date Quarterly/Annual (d)	MEGAWATT HOURS SOLD Amount Previous year (no Quarterly) (e)	AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly) (f)	AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly) (g)
1	SalesOfElectricityHeadingAbstract Sales of Electricity
2	ResidentialSalesAbstract (440) Residential Sales	724,600,968	748,427,734	5,483,701	5,493,694	384,611	384,283
3	CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales
4	CommercialSalesAbstract Small (or Comm.) (See Instr. 4)	(a) 577,483,804	(d) 604,342,791	4,587,902	4,637,290	66,358	66,572
5	IndustrialSalesAbstract Large (or Ind.) (See Instr. 4)	195,193,886	217,916,351	2,357,445	2,347,363	4,037	4,038
6	PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting	18,210,978	19,312,518	72,839	74,483	425	428
7	OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities	38,209,340	41,164,851	323,660	332,402	4,750	4,761
8	SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways
9	InterdepartmentalSalesAbstract (448) Interdepartmental Sales
10	SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers	1,553,698,976	1,631,164,245	12,825,547	12,885,232	460,181	460,082
11	SalesForResaleAbstract (447) Sales for Resale	126,001,144	98,254,907	5,467,295	4,416,997
12	SalesOfElectricityAbstract TOTAL Sales of Electricity	1,679,700,120	1,729,419,152	18,292,842	17,302,229	460,181	460,082
13	ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds
14	RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds	1,679,700,120	1,729,419,152	18,292,842	17,302,229	460,181	460,082
15	OtherOperatingRevenuesAbstract Other Operating Revenues
16	ForfeitedDiscounts (450) Forfeited Discounts	7,263,177	7,223,291
17	MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues	(b) 2,033,982	(e) 1,930,079
18	SalesOfWaterAndWaterPower (453) Sales of Water and Water Power
19	RentFromElectricProperty (454) Rent from Electric Property	12,657,247	11,979,476
20	InterdepartmentalRents (455) Interdepartmental Rents
21	OtherElectricRevenue (456) Other Electric Revenues	(c) 8,719,769	(f) 1,396,513
22	RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others	50,936,185	44,778,142
23	RegionalTransmissionServiceRevenues (457.1) Regional Control Service Revenues	595,469	92,609
24	MiscellaneousRevenue (457.2) Miscellaneous Revenues
25	OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues
26	OtherOperatingRevenues TOTAL Other Operating Revenues	82,205,829	67,400,110
27	ElectricOperatingRevenues TOTAL Electric Operating Revenues	1,761,905,949	1,796,819,262
Line12, column (b) includes $ of unbilled revenues.
Line12, column (d) includes MWH relating to unbilled revenues

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: SmallOrCommercialSalesElectricOperatingRevenue

Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.

(b) Concept: MiscellaneousServiceRevenues

Revenues from return charges and connection fee.

(c) Concept: OtherElectricRevenue

Other Electric Revenues include:


Unbilled Revenue - Includes (81,455) MWh			$4,275,183
Utility-owned Distributed Generation revenue			1,823,413
MISO Mkt Sch 11 Wholesale Dist			1,084,961
Ouachita Transmission Upgrade Reimbursement			970,860
Deposit Alternative Plan			363,714
Solar Service Fees			93,603
Annual Schedule 50 Billing			41,186
Vehicle Charging Station Sales			37,840
Green Power			23,661
Third Party Sales of Inventory			8,298
MS Department of Revenue Vendor Discount			1,200
Retail Bill Credits -System Energy Settlement			80
CIAC Excess Reimbursements			(4,230)
Total			$8,719,769

(d) Concept: SmallOrCommercialSalesElectricOperatingRevenue

Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.

(e) Concept: MiscellaneousServiceRevenues

Revenues from return charges and connection fee.

(f) Concept: OtherElectricRevenue


Other Electric Revenues include:
MISO Mkt Sch 11 Wholesale Dist			$1,089,318
Utility-Owned Distribution Generation Revenue			1,041,220
Ouachita Transmission Upgrade Reimbursement			970,860
Deposit Alternative Program			167,819
Solar Service Fees			90,440
Vehicle Charging Station Sales			25,177
Annual Schedule 50 Billing			18,800
Power Plant Reimbursement (Capital Project Excess)			6,147
Retail Bill Credits - System Energy Settlement			1,280
MS Department of Revenue Vendor Discount			1,150
Third Party Sales of Inventory			(7,534)
Unbilled Revenue - Includes (31,187) MWh			(2,008,164)
Total			$1,396,513

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.	Description of Service (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1	MISO Sch 1 Sched/Sys Ctrl/Disp	151,343	293,712	459,623	595,469
46	TOTAL	151,343	293,712	459,623	595,469

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	RS-40C Residential Service	4,144,032	548,379,093	303,838	13,639	0.1323
2	RS-40W Residential Water Heating Service	1,307,662	165,771,926	79,795	16,388	0.1268
3	PAL-17 Private Area Lighting	27,425	8,236,587	760	36,086	0.3003
4	UFL-16 Urban Flood Lighting	6	1,133	1	6,000	0.1888
5	RFL-16 Rural Flood Lighting	2	388	1	2,000	0.1940
6	DSL-16 Directional Security Lighting	1,332	417,260	63	21,143	0.3133
7	LED-2 LED Street and Area Lighting	3,242	1,876,287	153	21,190	0.5787
8	GS-300 General Lighting and Power		81,706
9	IPS-26 Irrigation Pumping Power
41	TOTAL Billed Residential Sales	5,483,701	(a) 724,600,968	384,611	14,258	0.1321
42	TOTAL Unbilled Rev. (See Instr. 6)
43	TOTAL	5,483,701	724,600,968	384,611	14,258	0.1321

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: ResidentialSalesBilled


Residential
Includes fuel adjustment revenues of:
RS-40C Residential Service			($82,497,953)
RS-40W Residential Water Heating Service			(24,424,214)
PAL-17 Private Area Lighting			(527,408)
UFL-16 Urban Flood Lighting			(118)
RFL-16 Rural Flood Lighting			(35)
DSL-16 Directional Security Lighting			(25,638)
GS-300 General Lighting and Power			3,817
HL-21 Public Highway & Park Lighting			—
LED-2 LED Street and Area Lighting			(63,135)
TOTAL RESIDENTIAL FUEL ADJUSTMENT REVENUES			($107,534,684)

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	GS-300 General Lighting and Power	2,438,923	362,905,544	63,934	38,148	0.1488
2	HLF-7 High Load Factor	1,182,317	110,349,940	328	3,604,625	0.0933
3	PAL-17 Private Area Lighting	12,124	3,997,167	822	14,749	0.3297
4	UFL-16 Urban Flood Lighting	175	32,306	11	15,909	0.1846
5	RFL-16 Rural Flood Lighting	7	1,588			0.2269
6	DSL-16 Directional Security Lighting	26,764	6,415,767	565	47,370	0.2397
7	LED-2 LED Street and Area Lighting	21,799	7,837,508	287	75,955	0.3595
8	B-34 Intermediate General Service	346,215	40,077,406	284	1,219,067	0.1158
9	SL-37 Municipal Street Lighting		26,557	3
10	TF-23 Traffic Control Signals
11	FAYETTE	432	25,981	1	432,000	0.0601
12	IPS-26 Irrigation Pumping Power
13	GS-300 MS Gen. Lghtg & Pwr Muni. Service
14	QF-24
15	Miscellaneous		8,669	85
16	ALGS-10 Alternate Large General Service	412,765	31,835,656	7	58,966,429	0.0771
17	MP-22 Municipal Pumping Power Service
18	GLP-17 Gen. Lghtg. & Pwr Redist. & Res.	1,394	186,260	1	1,394,000	0.1336
19	C-29 Large General Service	144,631	13,735,364	12	12,052,583	0.0950
20	SWH-20 Gen. Space and Water Heating Serv.	352	47,513	15	23,467	0.1350
21	RS-40C Residential Service	4	578	3	1,333	0.1445
22	RS-40W Residential Water Heating Service
41	TOTAL Billed Small or Commercial	4,587,902	(a) 577,483,804	66,358	69,139	0.1259
42	TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)
43	TOTAL Small or Commercial	4,587,902	(b) 577,483,804	66,358	69,139	0.1259

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: SmallOrCommercialSalesElectricOperatingRevenueBilled


Commercial
Includes Fuel Adjustment Revenues of:
GS-300 General Lighting and Power			($48,373,971)
B-34 Intermediate General Service			(6,722,611)
C-29 Large General Service			(2,826,212)
ALGS-10 Alternate Large General Service			(8,384,319)
HLF-7 High Load Factor General Service			(23,129,509)
FAYETTE			—
GLP-17 Gen. Lghtg. & Pwr for Redist. & Res.			(28,228)
DSL-16 Directional Security Lighting			(508,458)
SWH-20 Gen. Space and Water Heating Serv.			(6,704)
PAL-17 Private Area Lighting			($230,267)
UFL-16 Urban Flood Lighting			(3,359)
RFL-16 Rural Flood Lighting			(139)
RS-40C Residential Service			(96)
RS-40W Residential Water Heating Service			—
TF-23 Traffic Control Signal			—
MP-22 Municipal Pumping Power			—
IPS-26 Irrigation Pumping Power			—
HL-21 Public Highway & Park Lighting			—
SL-37 Municipal Street Lighting			—
LED-2 LED Street and Area Lighting			(418,499)
SE-29 State Institutions Service			—
GS-300 MS Gen L&P Muni Service			—
GS-298X Gen L&P TOU			—
TOTAL COMMERCIAL FUEL ADJUSTMENT REVENUES			($90,632,372)

(b) Concept: SmallOrCommercialSalesElectricOperatingRevenue

Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	GS-300 General Lighting and Power	129,272	18,653,995	2,089	61,882	0.1443
2	HLF-7 High Load Factor	567,635	52,884,240	89	6,377,921	0.0932
3	PAL-17 Private Area Lighting	501	148,456	20	25,050	0.2963
4	UFL-16 Urban Flood Lighting	6	1,279			0.2132
5	RFL-16 Rural Flood Lighting	2	388			0.1940
6	DSL-16 Directional Security Lighting	1,919	435,942	20	95,950	0.2272
7	LED-2 LED Street and Area Lighting	765	243,434	3	255,000	0.3182
8	B-34 Intermediate General Service	124,535	16,473,297	86	1,448,081	0.1323
9	C-29 Large General Service	223,484	22,445,977	28	7,981,571	0.1004
10	IPS-26 Irrigation Pumping Power	29,353	6,265,784	1,596	18,392	0.2135
11	IP-33 Ice Manufacturing Plant Power	67	9,805	1	67,000	0.1463
12	ALGS-10 / Other	726,388	59,279,199	17	42,728,706	0.0816
13	Contract Rates	518,107	16,312,344	4	129,526,750	0.0315
14	GS-298X	3,461	544,309	83	41,699	0.1573
15	GS-300 MS Gen. Lghtg & Pwr Muni. Service			0
16	RS-40C Residential Service			0
17	SL-37 Municipal Street Lighting	31,950	1,495,437	1	31,950,000	0.0468
41	TOTAL Billed Large (or Ind.) Sales	2,357,445	(a) 195,193,886	4,037	583,960	0.0828
42	TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)
43	TOTAL Large (or Ind.)	2,357,445	195,193,886	4,037	583,960	0.0828

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: LargeOrIndustrialSalesElectricOperatingRevenueBilled


Industrial
Includes Fuel Adjustment Revenues of:
GS-300 General Lighting and Power			($2,684,250)
B-34 Intermediate General Service			(2,463,831)
C-29 Large General Service			(4,372,036)
ALGS-10 / Other			(14,126,668)
HLF-7 High Load Factor General Service			(10,993,990)
DSL-16 Directional Security Lighting			(36,679)
IPS-26 Irrigation Pumping Power			(742,780)
IP-33 Ice Manufacturing Plant Power			(994)
PAL-17 Private Area Lighting Service			(9,626)
UFL-16 Urban Flood Lighting Service			(112)
RFL-16 Rural Flood Lighting Service			(35)
SL-37 Municipal Street Lighting			258,642
LED-2 LED Street and Area Lighting			(14,781)
GS-300 MS Gen L&P Muni Service			—
GS-298X Gen L&P TOU			(73,151)
CONTRACT RATES			(2,246,504)
TOTAL INDUSTRIAL FUEL ADJUSTMENT REVENUES			($37,506,795)

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	SL-37 Municipal Street Lighting	56,479	15,982,940	137	412,255	0.2830
2	HL-21 Public Highway & Park Lighting	12,258	1,483,855	85	144,212	0.1211
3	TF-23 Traffic Control Signals	4,023	704,277	193	20,845	0.1751
4	LED-2 LED Street and Area Lighting	79	39,906	10	7,900	0.5051
41	TOTAL Billed Public Street and Highway Lighting	72,839	(a) 18,210,978	425	171,386	0.2500
42	TOTAL Unbilled Rev. (See Instr. 6)
43	TOTAL	72,839	18,210,978	425	171,386	0.2500

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: PublicStreetAndHighwayLightingBilled


Public Street and Highway Lighting
Includes Fuel Adjustment Revenues of:
TF-23 Traffic Control Signals			($76,294)
HL-21 Public Highway & Park Lighting			(235,266)
SL-37 Municipal Street Lighting			(1,060,634)
DSL-16 Directional Security Lighting			—
PAL-17 Private Area Lighting Service			—
LED-2 LED Street and Area Lighting			(1,508)
TOTAL PUBLIC STREET AND HIGHWAY LIGHTING FUEL ADJUSTMENT REVENUES			($1,373,702)

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	GS-300 MS Gen. Lghtg & Pwr Muni. Service	170,344	20,470,732	2,728	62,443	0.1202
2	MP-22 Municipal Pumping Power Service	81,061	10,487,305	1,920	42,219	0.1294
3	SE-29 State Institutions	69,168	6,418,624	8	8,646,000	0.0928
4	GS-300 General Lighting and Power
5	SL-37 Municipal Street Lighting		455
6	PAL-17 Private Area Lighting	379	117,663	21	18,048	0.3105
7	DSL-16 Directional Security Lighting	1,923	453,419	62	31,016	0.2358
8	LED-2 LED Street and Area Lighting	780	260,377	11	70,909	0.3338
9	UFL-16 Urban Flood Lighting	5	765			0.1530
41	TOTAL Billed Other Sales to Public Authorities	323,660	(a) 38,209,340	4,750	68,139	0.1181
42	TOTAL Unbilled Rev. (See Instr. 6)
43	TOTAL	323,660	38,209,340	4,750	68,139	0.1181

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: OtherSalesToPublicAuthoritiesBilled


Other Sales to Public Authorities
Includes Fuel Adjustment Revenues of:
GS-300 MS Gen. Lghtg & Pwr Muni.Service			($3,392,445)
MP-22 Municipal Pumping Power Service			(1,514,575)
SE-29 State Institutions			(1,392,291)
DSL-16 Directional Security Lighting			(36,262)
PAL-17 Private Area Lighting			(7,064)
UFL-16 Urban Flood Lighting			(88)
HL-21 Public Highway & Park Ltg			—
GS-300 General Lighting and Power			—
RS-40W Residential Water Heating Service			—
LED-2 LED Street and Area Lighting			(15,069)
B-34 Intermediate General Service			—
TOTAL OTHER SALES TO PUBLIC AUTH FUEL ADJ REV			($6,357,794)

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
41	TOTAL Billed - All Accounts	12,825,547	1,553,698,976	460,181	27,871	0.1211
42	TOTAL Unbilled Rev. (See Instr. 6) - All Accounts
43	TOTAL - All Accounts	12,825,547	1,553,698,976	460,181	27,871	0.1211

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

SALES FOR RESALE (Account 447)
Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326). Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k). In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24. Footnote entries as required and provide explanations following all required data.
					ACTUAL DEMAND (MW)			REVENUE
Line No.	Name of Company or Public Authority (Footnote Affiliations) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Average Monthly Billing Demand (MW) (d)	Average Monthly NCP Demand (e)	Average Monthly CP Demand (f)	Megawatt Hours Sold (g)	Demand Charges ($) (h)	Energy Charges ($) (i)	Other Charges ($) (j)	Total ($) (h+i+j) (k)
1	Midcontinent ISO, Inc.	OS					5,467,295	937	122,956,477	(a) 3,043,730	126,001,144
15	Subtotal - RQ
16	Subtotal-Non-RQ						5,467,295	937	122,956,477	3,043,730	126,001,144
17	Total						5,467,295	937	122,956,477	3,043,730	126,001,144

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: OtherChargesRevenueSalesForResale


MISO Ancillary			($3,292)
MISO Residual Load			2,627,478
MISO Uplift			419,544
Total			$3,043,730

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

ELECTRIC OPERATION AND MAINTENANCE EXPENSES
If the amount for previous year is not derived from previously reported figures, explain in footnote.
Line No.	Account (a)	Amount for Current Year (b)	Amount for Previous Year (c) (c)
1	PowerProductionExpensesAbstract 1. POWER PRODUCTION EXPENSES
2	SteamPowerGenerationAbstract A. Steam Power Generation
3	SteamPowerGenerationOperationAbstract Operation
4	OperationSupervisionAndEngineeringSteamPowerGeneration (500) Operation Supervision and Engineering	3,267,407	3,072,303
5	FuelSteamPowerGeneration (501) Fuel	(a) 273,895,083	(b) 288,973,711
6	SteamExpensesSteamPowerGeneration (502) Steam Expenses	2,085,274	2,013,031
7	SteamFromOtherSources (503) Steam from Other Sources
8	SteamTransferredCredit (Less) (504) Steam Transferred-Cr.
9	ElectricExpensesSteamPowerGeneration (505) Electric Expenses	322,985	270,404
10	MiscellaneousSteamPowerExpenses (506) Miscellaneous Steam Power Expenses	6,343,849	7,498,836
11	RentsSteamPowerGeneration (507) Rents	46,566	85,756
12	Allowances (509) Allowances	2,803	3,401
13	SteamPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 4 thru 12)	285,963,967	301,917,442
14	SteamPowerGenerationMaintenanceAbstract Maintenance
15	MaintenanceSupervisionAndEngineeringSteamPowerGeneration (510) Maintenance Supervision and Engineering	262,040	326,210
16	MaintenanceOfStructuresSteamPowerGeneration (511) Maintenance of Structures	795,243	657,858
17	MaintenanceOfBoilerPlantSteamPowerGeneration (512) Maintenance of Boiler Plant	3,579,363	5,385,518
18	MaintenanceOfElectricPlantSteamPowerGeneration (513) Maintenance of Electric Plant	2,174,211	2,382,294
19	MaintenanceOfMiscellaneousSteamPlant (514) Maintenance of Miscellaneous Steam Plant	16,607,554	17,150,093
20	SteamPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 15 thru 19)	23,418,411	25,901,973
21	PowerProductionExpensesSteamPower TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)	309,382,378	327,819,415
22	NuclearPowerGenerationAbstract B. Nuclear Power Generation
23	NuclearPowerGenerationOperationAbstract Operation
24	OperationSupervisionAndEngineeringNuclearPowerGeneration (517) Operation Supervision and Engineering
25	NuclearFuelExpense (518) Fuel
26	CoolantsAndWater (519) Coolants and Water
27	SteamExpensesNuclearPowerGeneration (520) Steam Expenses
28	SteamFromOtherSourcesNuclearPowerGeneration (521) Steam from Other Sources
29	SteamTransferredCreditNuclearPowerGeneration (Less) (522) Steam Transferred-Cr.
30	ElectricExpensesNuclearPowerGeneration (523) Electric Expenses
31	MiscellaneousNuclearPowerExpenses (524) Miscellaneous Nuclear Power Expenses
32	RentsNuclearPowerGeneration (525) Rents
33	NuclearPowerGenerationOperationsExpense TOTAL Operation (Enter Total of lines 24 thru 32)
34	NuclearPowerGenerationMaintenanceAbstract Maintenance
35	MaintenanceSupervisionAndEngineeringNuclearPowerGeneration (528) Maintenance Supervision and Engineering
36	MaintenanceOfStructuresNuclearPowerGeneration (529) Maintenance of Structures
37	MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration (530) Maintenance of Reactor Plant Equipment
38	MaintenanceOfElectricPlantNuclearPowerGeneration (531) Maintenance of Electric Plant
39	MaintenanceOfMiscellaneousNuclearPlant (532) Maintenance of Miscellaneous Nuclear Plant
40	NuclearPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 35 thru 39)
41	PowerProductionExpensesNuclearPower TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)
42	HydraulicPowerGenerationAbstract C. Hydraulic Power Generation
43	HydraulicPowerGenerationOperationAbstract Operation
44	OperationSupervisionAndEngineeringHydraulicPowerGeneration (535) Operation Supervision and Engineering
45	WaterForPower (536) Water for Power
46	HydraulicExpenses (537) Hydraulic Expenses
47	ElectricExpensesHydraulicPowerGeneration (538) Electric Expenses
48	MiscellaneousHydraulicPowerGenerationExpenses (539) Miscellaneous Hydraulic Power Generation Expenses
49	RentsHydraulicPowerGeneration (540) Rents
50	HydraulicPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 44 thru 49)
51	HydraulicPowerGenerationContinuedAbstract C. Hydraulic Power Generation (Continued)
52	HydraulicPowerGenerationMaintenanceAbstract Maintenance
53	MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration (541) Mainentance Supervision and Engineering
54	MaintenanceOfStructuresHydraulicPowerGeneration (542) Maintenance of Structures
55	MaintenanceOfReservoirsDamsAndWaterways (543) Maintenance of Reservoirs, Dams, and Waterways
56	MaintenanceOfElectricPlantHydraulicPowerGeneration (544) Maintenance of Electric Plant
57	MaintenanceOfMiscellaneousHydraulicPlant (545) Maintenance of Miscellaneous Hydraulic Plant
58	HydraulicPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 53 thru 57)
59	PowerProductionExpensesHydraulicPower TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
60	OtherPowerGenerationAbstract D. Other Power Generation
61	OtherPowerGenerationOperationAbstract Operation
62	OperationSupervisionAndEngineeringOtherPowerGeneration (546) Operation Supervision and Engineering	687,255	987,257
63	Fuel (547) Fuel
64	GenerationExpenses (548) Generation Expenses	610,289	1,080,947
64.1	OperationOfEnergyStorageEquipment (548.1) Operation of Energy Storage Equipment
65	MiscellaneousOtherPowerGenerationExpenses (549) Miscellaneous Other Power Generation Expenses	11,929,125	12,035,265
66	RentsOtherPowerGeneration (550) Rents	120,510	134,793
67	OtherPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 62 thru 67)	13,347,179	14,238,262
68	OtherPowerGenerationMaintenanceAbstract Maintenance
69	MaintenanceSupervisionAndEngineeringOtherPowerGeneration (551) Maintenance Supervision and Engineering	42,811	73,860
70	MaintenanceOfStructures (552) Maintenance of Structures	289,502	497,314
71	MaintenanceOfGeneratingAndElectricPlant (553) Maintenance of Generating and Electric Plant	5,563,540	6,784,962
71.1	MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration (553.1) Maintenance of Energy Storage Equipment
72	MaintenanceOfMiscellaneousOtherPowerGenerationPlant (554) Maintenance of Miscellaneous Other Power Generation Plant	132,361	1,012,063
73	OtherPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 69 thru 72)	6,028,214	8,368,199
74	PowerProductionExpensesOtherPower TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)	19,375,393	22,606,461
75	OtherPowerSuplyExpensesAbstract E. Other Power Supply Expenses
76	PurchasedPower (555) Purchased Power	274,583,737	282,228,604
76.1	PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations
77	SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching	851,580	843,026
78	OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses	3,466,896	274,593,806
79	OtherPowerSupplyExpense TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)	271,968,421	557,665,436
80	PowerProductionExpenses TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)	600,726,192	908,091,312
81	TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES
82	TransmissionExpensesOperationAbstract Operation
83	OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering	2,723,799	3,041,266
85	LoadDispatchReliability (561.1) Load Dispatch-Reliability
86	LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System	2,025,707	1,926,646
87	LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling	39,441	42,540
88	SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services	4,508,205	3,719,733
89	ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development	547,420	529,389
90	TransmissionServiceStudies (561.6) Transmission Service Studies
91	GenerationInterconnectionStudies (561.7) Generation Interconnection Studies
92	ReliabilityPlanningAndStandardsDevelopmentServices (561.8) Reliability, Planning and Standards Development Services	598,602	285,753
93	StationExpensesTransmissionExpense (562) Station Expenses	256,894	159,474
93.1	OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment
94	OverheadLineExpense (563) Overhead Lines Expenses	1,357,552	889,377
95	UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses
96	TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others	612,770	146,459
97	MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses	1,511,107	1,486,391
98	RentsTransmissionElectricExpense (567) Rents	685,080	634,058
99	TransmissionOperationExpense TOTAL Operation (Enter Total of Lines 83 thru 98)	14,866,577	12,861,086
100	TransmissionMaintenanceAbstract Maintenance
101	MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering	3,596,463	3,087,936
102	MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures	199,167	82,486
103	MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware
104	MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software	42,776	106,084
105	MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment
106	MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant
107	MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment	2,362,354	3,043,818
107.1	MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment
108	MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines	1,605,014	4,024,424
109	MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines
110	MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant	277,321	92,855
111	TransmissionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 101 thru 110)	8,083,095	10,437,603
112	TransmissionExpenses TOTAL Transmission Expenses (Total of Lines 99 and 111)	22,949,672	23,298,689
113	RegionalMarketExpensesAbstract 3. REGIONAL MARKET EXPENSES
114	RegionalMarketExpensesOperationAbstract Operation
115	OperationSupervision (575.1) Operation Supervision
116	DayAheadAndRealTimeMarketAdministration (575.2) Day-Ahead and Real-Time Market Facilitation
117	TransmissionRightsMarketAdministration (575.3) Transmission Rights Market Facilitation
118	CapacityMarketAdministration (575.4) Capacity Market Facilitation
119	AncillaryServicesMarketAdministration (575.5) Ancillary Services Market Facilitation
120	MarketMonitoringAndCompliance (575.6) Market Monitoring and Compliance
121	MarketFacilitationMonitoringAndComplianceServices (575.7) Market Facilitation, Monitoring and Compliance Services	2,995,236	2,829,235
122	RentsRegionalMarketExpenses (575.8) Rents
123	RegionalMarketOperationExpense Total Operation (Lines 115 thru 122)	2,995,236	2,829,235
124	RegionalMarketExpensesMaintenanceAbstract Maintenance
125	MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses (576.1) Maintenance of Structures and Improvements
126	MaintenanceOfComputerHardware (576.2) Maintenance of Computer Hardware
127	MaintenanceOfComputerSoftware (576.3) Maintenance of Computer Software
128	MaintenanceOfCommunicationEquipmentRegionalMarketExpenses (576.4) Maintenance of Communication Equipment
129	MaintenanceOfMiscellaneousMarketOperationPlant (576.5) Maintenance of Miscellaneous Market Operation Plant
130	RegionalMarketMaintenanceExpense Total Maintenance (Lines 125 thru 129)
131	RegionalMarketExpenses TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)	2,995,236	2,829,235
132	DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES
133	DistributionExpensesOperationAbstract Operation
134	OperationSupervisionAndEngineeringDistributionExpense (580) Operation Supervision and Engineering	14,472,986	12,707,333
135	LoadDispatching (581) Load Dispatching	160,386	142,689
136	StationExpensesDistribution (582) Station Expenses	328,880	219,075
137	OverheadLineExpenses (583) Overhead Line Expenses	1,461,787	1,161,145
138	UndergroundLineExpenses (584) Underground Line Expenses	2,832,478	2,286,375
138.1	OperationOfEnergyStorageEquipmentDistribution (584.1) Operation of Energy Storage Equipment
139	StreetLightingAndSignalSystemExpenses (585) Street Lighting and Signal System Expenses	394,494	297,459
140	MeterExpenses (586) Meter Expenses	1,499,996	2,107,155
141	CustomerInstallationsExpenses (587) Customer Installations Expenses	1,033,974	954,848
142	MiscellaneousDistributionExpenses (588) Miscellaneous Expenses	6,272,095	4,707,241
143	RentsDistributionExpense (589) Rents	3,112,035	2,865,033
144	DistributionOperationExpensesElectric TOTAL Operation (Enter Total of Lines 134 thru 143)	31,569,111	27,448,353
145	DistributionExpensesMaintenanceAbstract Maintenance
146	MaintenanceSupervisionAndEngineering (590) Maintenance Supervision and Engineering	938,350	947,483
147	MaintenanceOfStructuresDistributionExpense (591) Maintenance of Structures	863,222	676,168
148	MaintenanceOfStationEquipment (592) Maintenance of Station Equipment	1,620,020	1,431,049
148.1	MaintenanceOfEnergyStorageEquipment (592.2) Maintenance of Energy Storage Equipment
149	MaintenanceOfOverheadLines (593) Maintenance of Overhead Lines	19,294,837	32,280,902
150	MaintenanceOfUndergroundLines (594) Maintenance of Underground Lines	1,563,627	1,691,031
151	MaintenanceOfLineTransformers (595) Maintenance of Line Transformers	24,701	122,414
152	MaintenanceOfStreetLightingAndSignalSystems (596) Maintenance of Street Lighting and Signal Systems	669,689	779,462
153	MaintenanceOfMeters (597) Maintenance of Meters	191,816	118,784
154	MaintenanceOfMiscellaneousDistributionPlant (598) Maintenance of Miscellaneous Distribution Plant	1,495,405	1,407,551
155	DistributionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 146 thru 154)	26,661,667	39,454,844
156	DistributionExpenses TOTAL Distribution Expenses (Total of Lines 144 and 155)	58,230,778	66,903,197
157	CustomerAccountsExpensesAbstract 5. CUSTOMER ACCOUNTS EXPENSES
158	CustomerAccountsExpensesOperationsAbstract Operation
159	SupervisionCustomerAccountExpenses (901) Supervision	411,401	424,338
160	MeterReadingExpenses (902) Meter Reading Expenses	1,092,158	867,872
161	CustomerRecordsAndCollectionExpenses (903) Customer Records and Collection Expenses	20,223,001	19,039,050
162	UncollectibleAccounts (904) Uncollectible Accounts	7,029,395	7,305,771
163	MiscellaneousCustomerAccountsExpenses (905) Miscellaneous Customer Accounts Expenses	64,100	97,664
164	CustomerAccountExpenses TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)	28,820,055	27,734,695
165	CustomerServiceAndInformationalExpensesAbstract 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166	CustomerServiceAndInformationalExpensesOperationAbstract Operation
167	SupervisionCustomerServiceAndInformationExpenses (907) Supervision	355,090	292,542
168	CustomerAssistanceExpenses (908) Customer Assistance Expenses	11,517,177	9,284,236
169	InformationalAndInstructionalAdvertisingExpenses (909) Informational and Instructional Expenses	330,594	296,147
170	MiscellaneousCustomerServiceAndInformationalExpenses (910) Miscellaneous Customer Service and Informational Expenses	1,436,992	1,585,012
171	CustomerServiceAndInformationExpenses TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)	13,639,853	11,457,937
172	SalesExpenseAbstract 7. SALES EXPENSES
173	SalesExpenseOperationAbstract Operation
174	SupervisionSalesExpense (911) Supervision	9,343	3,792
175	DemonstratingAndSellingExpenses (912) Demonstrating and Selling Expenses	1,924,184	2,305,245
176	AdvertisingExpenses (913) Advertising Expenses	22,934	294,769
177	MiscellaneousSalesExpenses (916) Miscellaneous Sales Expenses	623,362	192,857
178	SalesExpenses TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)	2,579,823	2,796,663
179	AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
180	AdministrativeAndGeneralExpensesOperationAbstract Operation
181	AdministrativeAndGeneralSalaries (920) Administrative and General Salaries	36,159,704	31,482,736
182	OfficeSuppliesAndExpenses (921) Office Supplies and Expenses	3,054,823	3,695,503
183	AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit	2,839,074	1,559,708
184	OutsideServicesEmployed (923) Outside Services Employed	20,679,848	22,772,013
185	PropertyInsurance (924) Property Insurance	28,112,002	23,636,374
186	InjuriesAndDamages (925) Injuries and Damages	4,993,753	8,747,341
187	EmployeePensionsAndBenefits (926) Employee Pensions and Benefits	23,743,318	24,371,997
188	FranchiseRequirements (927) Franchise Requirements
189	RegulatoryCommissionExpenses (928) Regulatory Commission Expenses	4,587,091	5,414,809
190	DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr.
191	GeneralAdvertisingExpenses (930.1) General Advertising Expenses	843,964	728,268
192	MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses	7,617,553	5,066,233
193	RentsAdministrativeAndGeneralExpense (931) Rents	458,398	519,332
194	AdministrativeAndGeneralOperationExpense TOTAL Operation (Enter Total of Lines 181 thru 193)	127,411,380	124,874,898
195	AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance
196	MaintenanceOfGeneralPlant (935) Maintenance of General Plant	1,302,777	1,447,351
197	AdministrativeAndGeneralExpenses TOTAL Administrative & General Expenses (Total of Lines 194 and 196)	128,714,157	126,322,249
198	OperationsAndMaintenanceExpensesElectric TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)	858,655,766	1,169,433,977

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: FuelSteamPowerGeneration

Includes $18,735,880 relating to certain gas hedging activities.

(b) Concept: FuelSteamPowerGeneration

Includes $56,790,402 relating to certain gas hedging activities.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

PURCHASED POWER (Account 555)
Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatthours shown on bills rendered to the respondent, excluding purchases for energy storage. Report in column (h) the megawatthours shown on bills rendered to the respondent for energy storage purchases. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. The data in columns (g) through (n) must be totaled on the last line of the schedule. The total amount in columns (g) and (h) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13. Footnote entries as required and provide explanations following all required data.
					Actual Demand (MW)				POWER EXCHANGES		COST/SETTLEMENT OF POWER
Line No.	NameOfCompanyOrPublicAuthorityProvidingPurchasedPower Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	RateScheduleTariffNumber Ferc Rate Schedule or Tariff Number (c)	AverageMonthlyBillingDemand Average Monthly Billing Demand (MW) (d)	AverageMonthlyNonCoincidentPeakDemand Average Monthly NCP Demand (e)	AverageMonthlyCoincidentPeakDemand Average Monthly CP Demand (f)	MegawattHoursPurchasedOtherThanStorage MegaWatt Hours Purchased (Excluding for Energy Storage) (g)	MegawattHoursPurchasedForEnergyStorage MegaWatt Hours Purchased for Energy Storage (h)	EnergyReceivedThroughPowerExchanges MegaWatt Hours Received (i)	EnergyDeliveredThroughPowerExchanges MegaWatt Hours Delivered (j)	DemandChargesOfPurchasedPower Demand Charges ($) (k)	EnergyChargesOfPurchasedPower Energy Charges ($) (l)	OtherChargesOfPurchasedPower Other Charges ($) (m)	SettlementOfPower Total (k+l+m) of Settlement ($) (n)
1	(a) System Energy Resources, Inc.	LU					3,163,533				175,695,097	20,602,916	(c) 10,435,796	206,733,809
2	(b) Entergy Arkansas, LLC	LU					666,063				35,462,690	4,364,524		39,827,214
3	Terra Miss Nitrogen	OS					451					12,689		12,689
4	CF Industries Nitrogen, LLC	OS					2,677					79,279		79,279
5	Midcontinent ISO, Inc.	OS	OATT				922,716				2,318,983	25,489,226	(d) 1,184,487	26,623,722
6	Small Residential Generation	OS					1,719					109,138		109,138
7	APX North American Renewable	OS											(e) 3,281	3,281
8	Sunflower	EX											(f) 1,214,605	1,214,605
9	Penton Solar	OS											(g) 20,000	20,000
15	TOTAL						4,757,159	0	0	0	213,476,770	50,657,772	10,449,195	274,583,737

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower

Energy and capacity charges from the Grand Gulf Nuclear Power Plant.

(b) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower

Energy and capacity charges associated with MSS-4.

(c) Concept: OtherChargesOfPurchasedPower

Represents $10,435,796 for deferral on over/under recovery under the Grand Gulf Rider.

(d) Concept: OtherChargesOfPurchasedPower


			CHARGES
MISO Ancillary			$839,174
MISO Congestion			(7,311,359)
MISO Losses			(1,105,349)
MISO Residual Load			2,657,010
MISO Uplift			3,489,465
MISO Administration			246,572
Total Other Purchases from MISO			($1,184,487)

(e) Concept: OtherChargesOfPurchasedPower

Renewal Energy Credit registration fee.

(f) Concept: OtherChargesOfPurchasedPower

Cost of power received under the contract for difference associated with Sunflower.

(g) Concept: OtherChargesOfPurchasedPower

Related to System Impact Studies for Transmission Service Requests for Network Integrated Transmission Service for solar facilities.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")

Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter.
Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c).
Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c).
In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided.
Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract.
Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain.
Report in column (i) and (j) the total megawatthours received and delivered.
In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (0) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively.
Footnote entries and provide explanations following all required data.

TRANSFER OF ENERGY

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS

Line No.

(a)

(b)

(c)

(d)

(e)

(f)

(g)

(h)

(i)

(j)

(k)

(l)

(m)

(n)

1

MISO

Various

50,936,185

35

TOTAL

0

50,936,185

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

TRANSMISSION OF ELECTRICITY BY ISO/RTOs
Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a). In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided. In column (d) report the revenue amounts as shown on bills or vouchers. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No.	Payment Received by (Transmission Owner Name) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Total Revenue by Rate Schedule or Tariff (d)	Total Revenue (e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
40	TOTAL

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. Enter ""TOTAL"" in column (a) as the last line. Footnote entries and provide explanations following all required data.
			TRANSFER OF ENERGY		EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.	NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	TransmissionOfElectricityByOthersEnergyReceived MegaWatt Hours Received (c)	TransmissionOfElectricityByOthersEnergyDelivered MegaWatt Hours Delivered (d)	DemandChargesTransmissionOfElectricityByOthers Demand Charges ($) (e)	EnergyChargesTransmissionOfElectricityByOthers Energy Charges ($) (f)	OtherChargesTransmissionOfElectricityByOthers Other Charges ($) (g)	ChargesForTransmissionOfElectricityByOthers Total Cost of Transmission ($) (h)
1	Midcontinent Independent System Operator Inc				(a) 540,152		(b) 72,618	612,770
	TOTAL		0	0	540,152	0	72,618	612,770

FOOTNOTE DATA

(a) Concept: DemandChargesTransmissionOfElectricityByOthers

The Utility operating companies are transmission owning members of the Midcontinent Independent System Operator (MISO) RTO. MISO is the transmission provider under the MISO Attachment O. Entergy Mississippi incurred charges from MISO for the purchase of network transmission service under the MISO Attachment O. MISO calculated the network service charges applicable to Entergy Mississippi and billed the entity for such service.

(b) Concept: OtherChargesTransmissionOfElectricityByOthers

Network upgrade charges incurred from MISO under the MISO Attachment O. Rates are calculated under Attachment GG. Charges are related to the MTEP (MISO Transmission Expansion Plan).

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.	Description (a)	Amount (b)
1	IndustryAssociationDues Industry Association Dues	156,242
2	NuclearPowerResearchExpenses Nuclear Power Research Expenses
3	OtherExperimentalAndGeneralResearchExpenses Other Experimental and General Research Expenses
4	PublicationAndDistributionExpensesForSecuritiesToStockholders Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities	230,661
5	OtherMiscellaneousGeneralExpenses Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6	5% surcharge on regulated billings to non-regulated affiliates	66,008
7	Directors meetings and expenses	99,752
8	Write-off of utility projects under contemplation	592,497
9	Mutual assistance	658,102
10	Federal infrastructure policy support	965,962
11	Transportation	17,004
12	IT software/hardware applications and software service contracts	5,031,837
13	Co-owner - Independence	909,272
14	Resource planning RFP	304,508
15	Other	33,928
46	MiscellaneousGeneralExpenses TOTAL	7,617,553

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
Report in section A for the year the amounts for: (b) Depreciation Expense (Account 403); (c) Depreciation Expense for Asset Retirement Costs (Account 403.1); (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405). Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year. Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used. In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used. For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type of mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
	A. Summary of Depreciation and Amortization Charges
Line No.	FunctionalClassificationAxis Functional Classification (a)	DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments Depreciation Expense (Account 403) (b)	DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments Depreciation Expense for Asset Retirement Costs (Account 403.1) (c)	AmortizationOfLimitedTermPlantOrProperty Amortization of Limited Term Electric Plant (Account 404) (d)	AmortizationOfOtherElectricPlant Amortization of Other Electric Plant (Acc 405) (e)	DepreciationAndAmortization Total (f)
1	Intangible Plant			28,468,966		28,468,966
2	Steam Production Plant	21,239,456	1,504,443			22,743,899
3	Nuclear Production Plant
4	Hydraulic Production Plant-Conventional
5	Hydraulic Production Plant-Pumped Storage
6	Other Production Plant	28,308,538				28,308,538
7	Transmission Plant	47,055,245				47,055,245
8	Distribution Plant	109,953,052				109,953,052
9	Regional Transmission and Market Operation
10	General Plant	(a) 27,628,550				27,628,550
11	Common Plant-Electric
12	TOTAL	234,184,841	1,504,443	28,468,966		264,158,250

B. Basis for Amortization Charges

	C. Factors Used in Estimating Depreciation Charges
Line No.	AccountNumberFactorsUsedInEstimatingDepreciationCharges Account No. (a)	DepreciablePlantBase Depreciable Plant Base (in Thousands) (b)	UtilityPlantEstimatedAverageServiceLife Estimated Avg. Service Life (c)	UtilityPlantNetSalvageValuePercentage Net Salvage (Percent) (d)	UtilityPlantAppliedDepreciationRate Applied Depr. Rates (Percent) (e)	MortalityCurveType Mortality Curve Type (f)	UtilityPlantWeightedAverageRemainingLife Average Remaining Life (g)
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments

Includes $4,239,515 of service company depreciation billing allocations.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

REGULATORY COMMISSION EXPENSES
Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous years, if being amortized) relating to format cases before a regulatory body, or cases in which such a body was a party. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization of amounts deferred in previous years. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization. List in columns (f), (g), and (h), expenses incurred during the year which were charged currently to income, plant, or other accounts. Minor items (less than $25,000) may be grouped.
						EXPENSES INCURRED DURING YEAR				AMORTIZED DURING YEAR
						CURRENTLY CHARGED TO
Line No.	RegulatoryCommissionDescription Description (Furnish name of regulatory commission or body the docket or case number and a description of the case) (a)	RegulatoryExpensesAssessedByRegulatoryCommission Assessed by Regulatory Commission (b)	RegulatoryExpensesOfUtility Expenses of Utility (c)	RegulatoryCommissionExpensesAmount Total Expenses for Current Year (b) + (c) (d)	OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 at Beginning of Year (e)	NameOfDepartmentRegulatoryCommissionExpensesCharged Department (f)	AccountNumberRegulatoryCommissionExpensesCharged Account No. (g)	RegulatoryComissionExpensesIncurredAndCharged Amount (h)	RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets Deferred to Account 182.3 (i)	DeferredRegulatoryCommissionExpensesAmortizedInContraAccount Contra Account (j)	DeferredRegulatoryCommissionExpensesAmortized Amount (k)	OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 End of Year (l)
1	Other expenses incurred in connection with various filings before the FERC including MMS-4 and SERI Litigation Dockets		119,303	119,303		Electric	928	119,303
2	Other expenses incurred in connection with MISO and other transmission related FERC dockets		84,325	84,325		Electric	928	84,325
3	MPSC Docket No. 2017-UA-189 - MISO Renewal Cost Benefit Analysis		1,667,874	1,667,874		Electric	928	1,667,874
4	MPSC Docket No. 2009-UN-388 - Attorney General Litigation		67,082	67,082	157,167	Electric	928			928	67,082	90,085
5	Other expenses incurred in connection with various filings before the MPSC		1,739,128	1,739,128		Electric	928	1,739,128
6	MPSC Docket No. 2022-UN-137 - EML Formula Rate Plan					Electic	928
7	MPSC Docket No. 2023-UN-142 - EML Formula Rate Plan					Electic	928
8	MPSC Docket No. 2024-UN-129- EML Formula Rate Plan		909,379	909,379		Electric	928	909,379
46	TOTAL		4,587,091	4,587,091	157,167			4,520,009			67,082	90,085

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D and D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(Identify recipient regardless of affiliation.) For any R, D and D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts). Indicate in column (a) the applicable classification, as shown below: Classifications: Electric R, D and D Performed Internally: Generation hydroelectric Recreation fish and wildlife Other hydroelectric Fossil-fuel steam Internal combustion or gas turbine Nuclear Unconventional generation Siting and heat rejection Transmission Overhead Underground Distribution Regional Transmission and Market Operation Environment (other than equipment) Other (Classify and include items in excess of $50,000.) Total Cost Incurred Electric, R, D and D Performed Externally: Research Support to the electrical Research Council or the Electric Power Research Institute Research Support to Edison Electric Institute Research Support to Nuclear Power Groups Research Support to Others (Classify) Total Cost Incurred Include in column (c) all R, D and D items performed internally and in column (d) those items performed outside the company costing $50,000 or more, briefly describing the specific area of R, D and D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D and D activity. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year, listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e). Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, Development, and Demonstration Expenditures, Outstanding at the end of the year. If costs have not been segregated for R, D and D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by ""Est."" Report separately research and related testing facilities operated by the respondent.
					AMOUNTS CHARGED IN CURRENT YEAR
Line No.	ResearchDevelopmentAndDemonstrationClassification Classification (a)	ResearchDevelopmentAndDemonstrationDescription Description (b)	ResearchDevelopmentAndDemonstrationCostsIncurredInternally Costs Incurred Internally Current Year (c)	ResearchDevelopmentAndDemonstrationCostsIncurredExternally Costs Incurred Externally Current Year (d)	AccountNumberForResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Account (e)	ResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Amount (f)	ResearchDevelopmentAndDemonstrationExpenditures Unamortized Accumulation (g)
1	A(2)	Transmission Design and Planning	51,921		107	51,921
2	A(2)	Transmission Delivery Standards	43,044		560	43,044
3	A(3)	Distribution sectionalization	10,000		107	10,000
4	B(4)	Transmission University Research		1,102	568	1,102
5	B(1)	EPRI dues		17,270	930.2	17,270
6	B(1)	EPRI (1)		121,457	580	121,457
7	B(1)	EPRI (2)		269,555	506	269,555
8	B(1)	EPRI (3)		90,306	560	90,306
9	B(2)	Edison Electric Institute		260,533	580	260,533
10	B(4)	SERC		598,590	561.8	598,590
11	B(4)	North American Transmission Forum Inc		43,173	560	43,173
12	B(4)	Distribution University Research		7,655	580	7,655

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

DISTRIBUTION OF SALARIES AND WAGES
Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used.
Line No.	Classification (a)	Direct Payroll Distribution (b)	Allocation of Payroll Charged for Clearing Accounts (c)	Total (d)
1	SalariesAndWagesElectricAbstract Electric
2	SalariesAndWagesElectricOperationAbstract Operation
3	SalariesAndWagesElectricOperationProduction Production	10,926,539
4	SalariesAndWagesElectricOperationTransmission Transmission	612,249
5	SalariesAndWagesElectricOperationRegionalMarket Regional Market
6	SalariesAndWagesElectricOperationDistribution Distribution	10,067,961
7	SalariesAndWagesElectricOperationCustomerAccounts Customer Accounts	2,405,933
8	SalariesAndWagesElectricOperationCustomerServiceAndInformational Customer Service and Informational	2,134,474
9	SalariesAndWagesElectricOperationSales Sales	182,060
10	SalariesAndWagesElectricOperationAdministrativeAndGeneral Administrative and General	6,144,180
11	SalariesAndWagesElectricOperation TOTAL Operation (Enter Total of lines 3 thru 10)	32,473,396
12	SalariesAndWagesElectricMaintenanceAbstract Maintenance
13	SalariesAndWagesElectricMaintenanceProduction Production	7,313,841
14	SalariesAndWagesElectricMaintenanceTransmission Transmission	2,637,210
15	SalariesAndWagesElectricMaintenanceRegionalMarket Regional Market
16	SalariesAndWagesElectricMaintenanceDistribution Distribution	6,165,897
17	SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral Administrative and General	250,190
18	SalariesAndWagesElectricMaintenance TOTAL Maintenance (Total of lines 13 thru 17)	16,367,138
19	SalariesAndWagesElectricOperationAndMaintenanceAbstract Total Operation and Maintenance
20	SalariesAndWagesElectricProduction Production (Enter Total of lines 3 and 13)	18,240,380
21	SalariesAndWagesElectricTransmission Transmission (Enter Total of lines 4 and 14)	3,249,459
22	SalariesAndWagesElectricRegionalMarket Regional Market (Enter Total of Lines 5 and 15)
23	SalariesAndWagesElectricDistribution Distribution (Enter Total of lines 6 and 16)	16,233,858
24	SalariesAndWagesElectricCustomerAccounts Customer Accounts (Transcribe from line 7)	2,405,933
25	SalariesAndWagesElectricCustomerServiceAndInformational Customer Service and Informational (Transcribe from line 8)	2,134,474
26	SalariesAndWagesElectricSales Sales (Transcribe from line 9)	182,060
27	SalariesAndWagesElectricAdministrativeAndGeneral Administrative and General (Enter Total of lines 10 and 17)	6,394,370
28	SalariesAndWagesElectricOperationAndMaintenance TOTAL Oper. and Maint. (Total of lines 20 thru 27)	48,840,534		48,840,534
29	SalariesAndWagesGasAbstract Gas
30	SalariesAndWagesGasOperationAbstract Operation
31	SalariesAndWagesGasOperationProductionManufacturedGas Production - Manufactured Gas
32	SalariesAndWagesGasOperationProductionNaturalGas Production-Nat. Gas (Including Expl. And Dev.)
33	SalariesAndWagesGasOperationOtherGasSupply Other Gas Supply
34	SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing Storage, LNG Terminaling and Processing
35	SalariesAndWagesGasOperationTransmission Transmission
36	SalariesAndWagesGasOperationDistribution Distribution
37	SalariesAndWagesGasCustomerAccounts Customer Accounts
38	SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational
39	SalariesAndWagesGasSales Sales
40	SalariesAndWagesGasOperationAdministrativeAndGeneral Administrative and General
41	SalariesAndWagesGasOperation TOTAL Operation (Enter Total of lines 31 thru 40)
42	SalariesAndWagesGasMaintenanceAbstract Maintenance
43	SalariesAndWagesGasMaintenanceProductionManufacturedGas Production - Manufactured Gas
44	SalariesAndWagesGasMaintenanceProductionNaturalGas Production-Natural Gas (Including Exploration and Development)
45	SalariesAndWagesGasMaintenanceOtherGasSupply Other Gas Supply
46	SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing
47	SalariesAndWagesGasMaintenanceTransmission Transmission
48	SalariesAndWagesGasMaintenanceDistribution Distribution
49	SalariesAndWagesGasMaintenanceAdministrativeAndGeneral Administrative and General
50	SalariesAndWagesGasMaintenance TOTAL Maint. (Enter Total of lines 43 thru 49)
51	SalariesAndWagesGasOperationAndMaintenanceAbstract Total Operation and Maintenance
52	SalariesAndWagesGasProductionManufacturedGas Production-Manufactured Gas (Enter Total of lines 31 and 43)
53	SalariesAndWagesGasProductionNaturalGas Production-Natural Gas (Including Expl. and Dev.) (Total lines 32,
54	SalariesAndWagesGasOtherGasSupply Other Gas Supply (Enter Total of lines 33 and 45)
55	SalariesAndWagesGasStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing (Total of lines 31 thru
56	SalariesAndWagesGasTransmission Transmission (Lines 35 and 47)
57	SalariesAndWagesGasDistribution Distribution (Lines 36 and 48)
58	SalariesAndWagesGasCustomerAccounts Customer Accounts (Line 37)
59	SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational (Line 38)
60	SalariesAndWagesGasSales Sales (Line 39)
61	SalariesAndWagesGasAdministrativeAndGeneral Administrative and General (Lines 40 and 49)
62	SalariesAndWagesGasOperationAndMaintenance TOTAL Operation and Maint. (Total of lines 52 thru 61)
63	SalariesAndWagesOtherUtilityDepartmentsAbstract Other Utility Departments
64	SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance Operation and Maintenance
65	SalariesAndWagesOperationsAndMaintenance TOTAL All Utility Dept. (Total of lines 28, 62, and 64)	48,840,534		48,840,534
66	SalariesAndWagesUtilityPlantAbstract Utility Plant
67	SalariesAndWagesUtilityPlantConstructionAbstract Construction (By Utility Departments)
68	SalariesAndWagesUtilityPlantConstructionElectricPlant Electric Plant	45,212,655		45,212,655
69	SalariesAndWagesUtilityPlantConstructionGasPlant Gas Plant
70	SalariesAndWagesUtilityPlantConstructionOther Other (provide details in footnote):
71	SalariesAndWagesUtilityPlantConstruction TOTAL Construction (Total of lines 68 thru 70)	45,212,655		45,212,655
72	SalariesAndWagesPlantRemovalAbstract Plant Removal (By Utility Departments)
73	SalariesAndWagesPlantRemovalElectricPlant Electric Plant	2,758,524		2,758,524
74	SalariesAndWagesPlantRemovalGasPlant Gas Plant
75	SalariesAndWagesPlantRemovalOther Other (provide details in footnote):
76	SalariesAndWagesPlantRemoval TOTAL Plant Removal (Total of lines 73 thru 75)	2,758,524		2,758,524
77	SalariesAndWagesOtherAccountsAbstract Other Accounts (Specify, provide details in footnote):
78	SalariesAndWagesOtherAccountsDescription Other Accounts (Specify, provide details in footnote):
79	SalariesAndWagesOtherAccountsDescription Preliminary Survey & Invtg (Account 183)	1,478		1,478
80	SalariesAndWagesOtherAccountsDescription Stores Expense Undistributed (Account 163)	2,418,339		2,418,339
81	SalariesAndWagesOtherAccountsDescription Miscellaneous Current and Accrued Assets (Account 174)	2,830,117		2,830,117
82	SalariesAndWagesOtherAccountsDescription Clearing Accounts (Account 184)	1,312,805		1,312,805
83	SalariesAndWagesOtherAccountsDescription Miscellaneous Deferred Debits (Account 186)	483,136		483,136
84	SalariesAndWagesOtherAccountsDescription Accumulated Provisions for Property Insurance (Account 2281)	9,568,315		9,568,315
85	SalariesAndWagesOtherAccountsDescription Accumulated Miscellaneous Operating Provisions (Account 2284)	3,032		3,032
86	SalariesAndWagesOtherAccountsDescription Civil, Political, and Related Expenses (Account 4264)	313,566		313,566
87	SalariesAndWagesOtherAccountsDescription Other Deductions (Account 4265)	18,766		18,766
88	SalariesAndWagesOtherAccountsDescription Employment Taxes (Account 40811)	73,611		73,611
89	SalariesAndWagesOtherAccountsDescription
90	SalariesAndWagesOtherAccountsDescription
91	SalariesAndWagesOtherAccountsDescription
92	SalariesAndWagesOtherAccountsDescription
93	SalariesAndWagesOtherAccountsDescription
94	SalariesAndWagesOtherAccountsDescription
95	SalariesAndWagesOtherAccounts TOTAL Other Accounts	17,023,165		17,023,165
96	SalariesAndWagesGeneralExpense TOTAL SALARIES AND WAGES	113,834,878		(a) 113,834,878

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: SalariesAndWagesGeneralExpense

The following payroll charges from Entergy Services are not included in this schedule and are included in the Electric O&M schedule (pages 320-323) only:


			CHARGES
Production:			$6,507,868
Transmission:			$5,164,318
Distribution:			$4,777,595
Customer Accts:			$3,847,964
Customer Service:			$534,624
Sales:			$1,012,419
Administrative & General:			$26,084,914

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

COMMON UTILITY PLANT AND EXPENSES
Describe the property carried in the utility's accounts as common utility plant and show the book cost of such plant at end of year classified by accounts as provided by Electric Plant Instruction 13, Common Utility Plant, of the Uniform System of Accounts. Also show the allocation of such plant costs to the respective departments using the common utility plant and explain the basis of allocation used, giving the allocation factors. Furnish the accumulated provisions for depreciation and amortization at end of year, showing the amounts and classifications of such accumulated provisions, and amounts allocated to utility departments using the common utility plant to which such accumulated provisions relate, including explanation of basis of allocation and factors used. Give for the year the expenses of operation, maintenance, rents, depreciation, and amortization for common utility plant classified by accounts as provided by the Uniform System of Accounts. Show the allocation of such expenses to the departments using the common utility plant to which such expenses are related. Explain the basis of allocation used and give the factors of allocation. Give date of approval by the Commission for use of the common utility plant classification and reference to the order of the Commission or other authorization.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No.	Description of Item(s) (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1	Energy
2	Net Purchases (Account 555)	5,501,069	13,453,477	20,764,014	25,489,226
2.1	Net Purchases (Account 555.1)
3	Net Sales (Account 447)	46,651,932	65,654,747	90,242,255	122,956,477
4	Transmission Rights
5	Ancillary Services
6	Other Items (list separately)
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46	TOTAL	52,153,001	79,108,224	111,006,269	148,445,703

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

PURCHASES AND SALES OF ANCILLARY SERVICES
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff. In columns for usage, report usage-related billing determinant and the unit of measure. On Line 1 columns (b), (c), (d), and (e) report the amount of ancillary services purchased and sold during the year. On Line 2 columns (b), (c), (d), and (e) report the amount of reactive supply and voltage control services purchased and sold during the year. On Line 3 columns (b), (c), (d), and (e) report the amount of regulation and frequency response services purchased and sold during the year. On Line 4 columns (b), (c), (d), and (e) report the amount of energy imbalance services purchased and sold during the year. On Lines 5 and 6, columns (b), (c), (d), and (e) report the amount of operating reserve spinning and supplement services purchased and sold during the period. On Line 7 columns (b), (c), (d), and (e) report the total amount of all other types ancillary services purchased or sold during the year. Include in a footnote and specify the amount for each type of other ancillary service provided.
		Amount Purchased for the Year			Amount Sold for the Year
		Usage - Related Billing Determinant			Usage - Related Billing Determinant
Line No.	Type of Ancillary Service (a)	Number of Units (b)	Unit of Measure (c)	Dollar (d)	Number of Units (e)	Unit of Measure (f)	Dollars (g)
1	Scheduling, System Control and Dispatch						595,469
2	Reactive Supply and Voltage			100,775
3	Regulation and Frequency Response
4	Energy Imbalance
5	Operating Reserve - Spinning
6	Operating Reserve - Supplement
7	Other
8	Total (Lines 1 thru 7)			100,775			(a) 595,469

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: AncillaryServicesSoldAmount

Entergy Mississippi is a transmission owning member of Midwest Independent Transmission System Operator (MISO) RTO. Entergy Mississippi does not purchase or sell transmission services or ancillary services directly. Instead, Entergy Mississippi receives revenues and incurs expenses from transmission services and ancillary sold by MISO. MISO distributes the revenue that it receives to the transmission owner and the transmission owner pays MISO for the related expenses incurred.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

MONTHLY TRANSMISSION SYSTEM PEAK LOAD
Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No.	Month (a)	Monthly Peak MW - Total (b)	Day of Monthly Peak (c)	Hour of Monthly Peak (d)	Firm Network Service for Self (e)	Firm Network Service for Others (f)	Long-Term Firm Point-to-point Reservations (g)	Other Long-Term Firm Service (h)	Short-Term Firm Point-to-point Reservation (i)	Other Service (j)
	NAME OF SYSTEM: Entergy Mississippi, LLC
1	January	3,211	17	9	2,388	823
2	February	2,346	19	8	1,767	579
3	March	2,255	19	8	1,746	509
4	Total for Quarter 1				5,901	1,911	0	0	0	0
5	April	2,165	30	18	1,683	482
6	May	2,855	27	16	2,205	650
7	June	3,639	25	17	2,800	839
8	Total for Quarter 2				6,688	1,971	0	0	0	0
9	July	3,630	16	16	2,801	829
10	August	3,671	6	16	2,818	853
11	September	3,274	3	17	2,586	688
12	Total for Quarter 3				8,205	2,370	0	0	0	0
13	October	2,643	5	16	2,061	582
14	November	2,216	4	16	1,728	488
15	December	2,499	6	9	1,884	615
16	Total for Quarter 4				5,673	1,685	0	0	0	0
17	Total				26,467	7,937	0	0	0	0

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

Monthly ISO/RTO Transmission System Peak Load
Report the monthly peak load on the respondent's transmission system. If the Respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Column (c) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (i) by month the system’s transmission usage by classification. Amounts reported as Through and Out Service in Column (g) are to be excluded from those amounts reported in Columns (e) and (f). Amounts reported in Column (j) for Total Usage is the sum of Columns (h) and (i).
Line No.	Month (a)	Monthly Peak MW - Total (b)	Day of Monthly Peak (c)	Hour of Monthly Peak (d)	Import into ISO/RTO (e)	Exports from ISO/RTO (f)	Through and Out Service (g)	Network Service Usage (h)	Point-to-Point Service Usage (i)	Total Usage (j)
	NAME OF SYSTEM: 0
1	January									0
2	February									0
3	March									0
4	Total for Quarter 1				0	0	0	0	0	0
5	April									0
6	May									0
7	June									0
8	Total for Quarter 2				0	0	0	0	0	0
9	July									0
10	August									0
11	September									0
12	Total for Quarter 3				0	0	0	0	0	0
13	October									0
14	November									0
15	December									0
16	Total for Quarter 4				0	0	0	0	0	0
17	Total Year to Date/Year				0	0	0	0	0	0

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2025-04-15

Year/Period of Report

End of:

2024

/

Q4

ELECTRIC ENERGY ACCOUNT
Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year.
Line No.	Item (a)	MegaWatt Hours (b)	Line No.	Item (a)	MegaWatt Hours (b)
1	SOURCES OF ENERGY		21	DISPOSITION OF ENERGY
2	Generation (Excluding Station Use):		22	Sales to Ultimate Consumers (Including Interdepartmental Sales)	12,825,547
3	Steam	14,188,720	23	Requirements Sales for Resale (See instruction 4, page 311.)
4	Nuclear		24	Non-Requirements Sales for Resale (See instruction 4, page 311.)	5,467,295
5	Hydro-Conventional		25	Energy Furnished Without Charge
6	Hydro-Pumped Storage		26	Energy Used by the Company (Electric Dept Only, Excluding Station Use)	15,896
7	Other	778	27	Total Energy Losses	637,919
8	Less Energy for Pumping		27.1	Total Energy Stored
9	Net Generation (Enter Total of lines 3 through 8)	14,189,498	28	TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES	18,946,657
10	Purchases (other than for Energy Storage)	4,757,159
10.1	Purchases for Energy Storage	0
11	Power Exchanges:
12	Received	0
13	Delivered	0
14	Net Exchanges (Line 12 minus line 13)	0
15	Transmission For Other (Wheeling)
16	Received
17	Delivered
18	Net Transmission for Other (Line 16 minus line 17)	0
19	Transmission By Others Losses
20	TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19)	18,946,657

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

MONTHLY PEAKS AND OUTPUT
Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system. Report in column (b) by month the system’s output in Megawatt hours for each month. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).
Line No.	MonthAxis Month (a)	EnergyActivity Total Monthly Energy (b)	NonRequiredSalesForResaleEnergy Monthly Non-Requirement Sales for Resale & Associated Losses (c)	MonthlyPeakLoad Monthly Peak - Megawatts (d)	DayOfMonthlyPeak Monthly Peak - Day of Month (e)	HourOfMonthlyPeak Monthly Peak - Hour (f)
	NAME OF SYSTEM: Entergy Mississippi, LLC
29	January	1,908,800	704,082	2,478	17	9
30	February	1,646,432	768,865	1,871	19	9
31	March	1,310,545	484,582	1,695	19	8
32	April	1,147,625	248,880	1,849	30	18
33	May	1,597,870	468,674	2,297	27	16
34	June	1,602,709	199,582	2,768	25	17
35	July	1,883,595	434,241	2,891	31	17
36	August	1,922,518	432,046	2,907	28	16
37	September	1,592,829	409,442	2,629	3	17
38	October	1,410,515	361,822	2,152	1	16
39	November	1,199,393	261,534	1,815	4	16
40	December	1,723,826	693,545	1,993	6	9
41	Total	18,946,657	5,467,295

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

Steam Electric Generating Plant Statistics

1. Report data for plant in Service only.
2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Report in this page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants.
3. Indicate by a footnote any plant leased or operated as a joint facility.
4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.
5. If any employees attend more than one plant, report on line 11 the approximate average number of employees assignable to each plant.
6. If gas is used and purchased on a therm basis report the Btu content or the gas and the quantity of fuel burned converted to Mcf.
7. Quantities of fuel burned (Line 38) and average cost per unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20.
8. If more than one fuel is burned in a plant furnish only the composite heat rate for all fuels burned.
9. Items under Cost of Plant are based on USofA accounts. Production expenses do not include Purchased Power, System Control and Load Dispatching, and Other Expenses Classified as Other Power Supply Expenses.
10. For IC and GT plants, report Operating Expenses, Account Nos. 547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plants designed for peak load service. Designate automatically operated plants.
11. For a plant equipped with combinations of fossil fuel steam, nuclear steam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combined cycle operation with a conventional steam unit, include the gas-turbine with the steam plant.
12. If a nuclear power generating plant, briefly explain by footnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost units used for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for the report period and other physical and operating characteristics of plant.

Line No.	Item (a)	Plant Name: Attala	Plant Name: Baxter Wilson	Plant Name: Choctaw	Plant Name: Gerald Andrus	Plant Name: Hinds	Plant Name: (a) Independence
1	PlantKind Kind of Plant (Internal Comb, Gas Turb, Nuclear)	Gas Turbine	Steam	Combined Cycle	Steam	Gas Turbine	Steam
2	PlantConstructionType Type of Constr (Conventional, Outdoor, Boiler, etc)		Outdoor Boiler	Outdoor	Outdoor Boiler		Outdoor Boiler
3	YearPlantOriginallyConstructed Year Originally Constructed	1905	1905	2019	1975	2001	1983
4	YearLastUnitOfPlantInstalled Year Last Unit was Installed	1905	1971	2019	1975	2001	1984
5	InstalledCapacityOfPlant Total Installed Cap (Max Gen Name Plate Ratings-MW)	551	545	899	781	600	1,800
6	NetPeakDemandOnPlant Net Peak Demand on Plant - MW (60 minutes)	524	0	934	733	551	1,710
7	PlantHoursConnectedToLoad Plant Hours Connected to Load	6,403	0	7,591	1,090	7,675	11,151
8	NetContinuousPlantCapability Net Continuous Plant Capability (Megawatts)
9	NetContinuousPlantCapabilityNotLimitedByCondenserWater When Not Limited by Condenser Water	501	559	848	750	526	1,681
10	NetContinuousPlantCapabilityLimitedByCondenserWater When Limited by Condenser Water	458	494	808	707	481	1,666
11	PlantAverageNumberOfEmployees Average Number of Employees	25	3	29	29	35	49
12	NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh	2,985,306,459		6,023,802,111	388,515,883	3,437,965,507	1,353,129,719
13	CostOfLandAndLandRightsSteamProduction Cost of Plant: Land and Land Rights	128,931	90,432	2,761,498	331,301	1,362,657	1,068,160
14	CostOfStructuresAndImprovementsSteamProduction Structures and Improvements	20,408,260	335,352	208,915,452	32,031,715	102,078,007	22,248,247
15	CostOfEquipmentSteamProduction Equipment Costs	138,523,424		295,629,946	172,720,038	246,002,878	260,620,496
16	AssetRetirementCostsSteamProduction Asset Retirement Costs		136,135		2,038,924		11,321,605
17	CostOfPlant Total cost (total 13 thru 20)	159,060,615	561,919	507,306,896	207,121,978	349,443,542	295,258,508
18	CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 17/5) Including	289	1	564	265	582	164
19	OperationSupervisionAndEngineeringExpense Production Expenses: Oper, Supv, & Engr	688,888	4,749	546,235	1,468,809	659,903	586,078
20	FuelSteamPowerGeneration Fuel	43,514,503	120,626	105,492,331	12,774,353	58,129,361	35,143,486
21	CoolantsAndWater Coolants and Water (Nuclear Plants Only)						0
22	SteamExpensesSteamPowerGeneration Steam Expenses	18,766	5,424	31,761	1,682,101	19,701	327,521
23	SteamFromOtherSources Steam From Other Sources						0
24	SteamTransferredCredit Steam Transferred (Cr)						0
25	ElectricExpensesSteamPowerGeneration Electric Expenses	523,479	3,483		13,021	86,810	306,481
26	MiscellaneousSteamPowerExpenses Misc Steam (or Nuclear) Power Expenses	5,991,594	261,713	1,134,739	3,071,191	6,192,518	1,336,162
27	RentsSteamPowerGeneration Rents	108,422		8,165	17,611	21,976	10,902
28	Allowances Allowances	79		177	1,114	122	1,311
29	MaintenanceSupervisionAndEngineeringSteamPowerGeneration Maintenance Supervision and Engineering	59,184		29,922	176,175	19,865	19,705
30	MaintenanceOfStructuresSteamPowerGeneration Maintenance of Structures	172,286		25,939	464,762	148,631	273,127
31	MaintenanceOfBoilerPlantSteamPowerGeneration Maintenance of Boiler (or reactor) Plant	512		868	1,368,768	538	2,208,677
32	MaintenanceOfElectricPlantSteamPowerGeneration Maintenance of Electric Plant	2,487,337		6,248	911,282	3,083,771	1,249,113
33	MaintenanceOfMiscellaneousSteamPlant Maintenance of Misc Steam (or Nuclear) Plant	372,259		13,077,752	640,743	428,003	2,221,158
34	PowerProductionExpensesSteamPower Total Production Expenses	53,937,309	395,995	120,354,137	22,589,930	68,791,199	43,683,721
35	ExpensesPerNetKilowattHour Expenses per Net kWh	0.0181		0.0200	0.0581	0.0200	0.0323

35	FuelKindAxis Plant Name	Attala	Baxter Wilson	Baxter Wilson	Choctaw	Gerald Andrus	Gerald Andrus	Hinds	Independence	Independence
36	FuelKind Fuel Kind	Gas	Gas	Oil	Gas	Gas	Oil	Gas	Coal	Oil
37	FuelUnit Fuel Unit	Mcf	Mcf	bbl	Mcf	Mcf	bbl	Mcf	T	bbl
38	QuantityOfFuelBurned Quantity (Units) of Fuel Burned	18,551,298	0	0	39,655,818	4,258,711	640	23,475,102	82,014	4,309
39	FuelBurnedAverageHeatContent Avg Heat Cont - Fuel Burned (btu/indicate if nuclear)	1,046,054	0	0	1,065,951	1,029,364	140,476	1,058,774	87,484	140,476
40	AverageCostOfFuelPerUnitAsDelivered Avg Cost of Fuel/unit, as Delvd f.o.b. during year
41	AverageCostOfFuelPerUnitBurned Average Cost of Fuel per Unit Burned	2			3	3	224	2	422	62
42	AverageCostOfFuelBurnedPerMillionBritishThermalUnit Average Cost of Fuel Burned per Million BTU	2			2	3	38	2	2	11
43	AverageCostOfFuelBurnedPerKilowattHourNetGeneration Average Cost of Fuel Burned per kWh Net Gen
44	AverageBritishThermalUnitPerKilowattHourNetGeneration Average BTU per kWh Net Generation	6,500			7,017	11,293		7,230	19,371

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: PlantName

Indepedence - Reflects Entergy Mississippi's 25% ownership interest in Independence Units 1 and 2.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

Hydroelectric Generating Plant Statistics

Large plants are hydro plants of 10,000 Kw or more of installed capacity (name plate ratings).
If any plant is leased, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. If licensed project, give project number.
If net peak demand for 60 minutes is not available, give that which is available specifying period.
If a group of employees attends more than one generating plant, report on line 11 the approximate average number of employees assignable to each plant.
The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power, System control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses."
Report as a separate plant any plant equipped with combinations of steam, hydro, internal combustion engine, or gas turbine equipment.

Line No.	Item (a)	FERC Licensed Project No. 0 Plant Name: 0
1	PlantKind Kind of Plant (Run-of-River or Storage)
2	PlantConstructionType Plant Construction type (Conventional or Outdoor)
3	YearPlantOriginallyConstructed Year Originally Constructed
4	YearLastUnitOfPlantInstalled Year Last Unit was Installed
5	InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW)
6	NetPeakDemandOnPlant Net Peak Demand on Plant-Megawatts (60 minutes)
7	PlantHoursConnectedToLoad Plant Hours Connect to Load
8	NetPlantCapabilityAbstract Net Plant Capability (in megawatts)
9	NetPlantCapabilityUnderMostFavorableOperatingConditions (a) Under Most Favorable Oper Conditions
10	NetPlantCapabilityUnderMostAdverseOperatingConditions (b) Under the Most Adverse Oper Conditions
11	PlantAverageNumberOfEmployees Average Number of Employees
12	NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh
13	CostOfPlantAbstract Cost of Plant
14	CostOfLandAndLandRightsHydroelectricProduction Land and Land Rights
15	CostOfStructuresAndImprovementsHydroelectricProduction Structures and Improvements
16	CostOfReservoirsDamsAndWaterwaysHydroelectricProduction Reservoirs, Dams, and Waterways
17	EquipmentCostsHydroelectricProduction Equipment Costs
18	CostOfRoadsRailroadsAndBridgesHydroelectricProduction Roads, Railroads, and Bridges
19	AssetRetirementCostsHydroelectricProduction Asset Retirement Costs
20	CostOfPlant Total cost (total 13 thru 20)
21	CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 20 / 5)
22	ProductionExpensesAbstract Production Expenses
23	OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering
24	WaterForPower Water for Power
25	HydraulicExpenses Hydraulic Expenses
26	ElectricExpensesHydraulicPowerGeneration Electric Expenses
27	MiscellaneousHydraulicPowerGenerationExpenses Misc Hydraulic Power Generation Expenses
28	RentsHydraulicPowerGeneration Rents
29	MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration Maintenance Supervision and Engineering
30	MaintenanceOfStructuresHydraulicPowerGeneration Maintenance of Structures
31	MaintenanceOfReservoirsDamsAndWaterways Maintenance of Reservoirs, Dams, and Waterways
32	MaintenanceOfElectricPlantHydraulicPowerGeneration Maintenance of Electric Plant
33	MaintenanceOfMiscellaneousHydraulicPlant Maintenance of Misc Hydraulic Plant
34	PowerProductionExpensesHydraulicPower Total Production Expenses (total 23 thru 33)
35	ExpensesPerNetKilowattHour Expenses per net kWh

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

Pumped Storage Generating Plant Statistics
Large plants and pumped storage plants of 10,000 Kw or more of installed capacity (name plate ratings). If any plant is leased, operating under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, indicate such facts in a footnote. Give project number. If net peak demand for 60 minutes is not available, give that which is available, specifying period. If a group of employees attends more than one generating plant, report on Line 8 the approximate average number of employees assignable to each plant. The items under Cost of Plant represent accounts or combinations of accounts prescribed by the Uniform System of Accounts. Production Expenses do not include Purchased Power System Control and Load Dispatching, and Other Expenses classified as "Other Power Supply Expenses." Pumping energy (Line 10) is that energy measured as input to the plant for pumping purposes. Include on Line 36 the cost of energy used in pumping into the storage reservoir. When this item cannot be accurately computed leave Lines 36, 37 and 38 blank and describe at the bottom of the schedule the company's principal sources of pumping power, the estimated amounts of energy from each station or other source that individually provides more than 10 percent of the total energy used for pumping, and production expenses per net MWH as reported herein for each source described. Group together stations and other resources which individually provide less than 10 percent of total pumping energy. If contracts are made with others to purchase power for pumping, give the supplier contract number, and date of contract.
Line No.	Item (a)	FERC Licensed Project No. 0 Plant Name: 0
1	PlantConstructionType Type of Plant Construction (Conventional or Outdoor)
2	YearPlantOriginallyConstructed Year Originally Constructed
3	YearLastUnitOfPlantInstalled Year Last Unit was Installed
4	InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW)
5	NetPeakDemandOnPlant Net Peak Demaind on Plant-Megawatts (60 minutes)
6	PlantHoursConnectedToLoad Plant Hours Connect to Load While Generating
7	NetContinuousPlantCapability Net Plant Capability (in megawatts)
8	PlantAverageNumberOfEmployees Average Number of Employees
9	NetGenerationExcludingPlantUse Generation, Exclusive of Plant Use - kWh
10	EnergyUsedForPumping Energy Used for Pumping
11	NetOutputForLoad Net Output for Load (line 9 - line 10) - Kwh	0
12	CostOfPlantAbstract Cost of Plant
13	CostOfLandAndLandRightsPumpedStoragePlant Land and Land Rights
14	CostOfStructuresAndImprovementsPumpedStoragePlant Structures and Improvements
15	CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant Reservoirs, Dams, and Waterways
16	CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant Water Wheels, Turbines, and Generators
17	CostOfAccessoryElectricEquipmentPumpedStoragePlant Accessory Electric Equipment
18	CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant Miscellaneous Powerplant Equipment
19	CostOfRoadsRailroadsAndBridgesPumpedStoragePlant Roads, Railroads, and Bridges
20	AssetRetirementCostsPumpedStoragePlant Asset Retirement Costs
21	CostOfPlant Total cost (total 13 thru 20)
22	CostPerKilowattOfInstalledCapacity Cost per KW of installed cap (line 21 / 4)
23	ProductionExpensesAbstract Production Expenses
24	OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering
25	WaterForPower Water for Power
26	PumpedStorageExpenses Pumped Storage Expenses
27	ElectricExpensesPumpedStoragePlant Electric Expenses
28	MiscellaneousPumpedStoragePowerGenerationExpenses Misc Pumped Storage Power generation Expenses
29	RentsPumpedStoragePlant Rents
30	MaintenanceSupervisionAndEngineeringPumpedStoragePlant Maintenance Supervision and Engineering
31	MaintenanceOfStructuresPumpedStoragePlant Maintenance of Structures
32	MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant Maintenance of Reservoirs, Dams, and Waterways
33	MaintenanceOfElectricPlantPumpedStoragePlant Maintenance of Electric Plant
34	MaintenanceOfMiscellaneousPumpedStoragePlant Maintenance of Misc Pumped Storage Plant
35	PowerProductionExpenseBeforePumpingExpenses Production Exp Before Pumping Exp (24 thru 34)
36	PumpingExpenses Pumping Expenses
37	PowerProductionExpensesPumpedStoragePlant Total Production Exp (total 35 and 36)
38	ExpensesPerNetKilowattHour Expenses per kWh (line 37 / 9)
39	ExpensesPerNetKilowattHourGenerationAndPumping Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10))	0

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

GENERATING PLANT STATISTICS (Small Plants)
Small generating plants are steam plants of, less than 25,000 Kw; internal combustion and gas turbine-plants, conventional hydro plants and pumped storage plants of less than 10,000 Kw installed capacity (name plate rating). Designate any plant leased from others, operated under a license from the Federal Energy Regulatory Commission, or operated as a joint facility, and give a concise statement of the facts in a footnote. If licensed project, give project number in footnote. List plants appropriately under subheadings for steam, hydro, nuclear, internal combustion and gas turbine plants. For nuclear, see instruction 11, Page 402. If net peak demand for 60 minutes is not available, give the which is available, specifying period. If any plant is equipped with combinations of steam, hydro internal combustion or gas turbine equipment, report each as a separate plant. However, if the exhaust heat from the gas turbine is utilized in a steam turbine regenerative feed water cycle, or for preheated combustion air in a boiler, report as one plant.
									Production Expenses
Line No.	PlantName Name of Plant (a)	YearPlantOriginallyConstructed Year Orig. Const. (b)	InstalledCapacityOfPlant Installed Capacity Name Plate Rating (MW) (c)	NetPeakDemandOnPlant Net Peak Demand MW (60 min) (d)	NetGenerationExcludingPlantUse Net Generation Excluding Plant Use (e)	CostOfPlant Cost of Plant (f)	PlantCostPerMw Plant Cost (Incl Asset Retire. Costs) Per MW (g)	OperatingExpensesExcludingFuel Operation Exc'l. Fuel (h)	FuelProductionExpenses Fuel Production Expenses (i)	MaintenanceProductionExpenses Maintenance Production Expenses (j)	FuelKind Kind of Fuel (k)	FuelCostPerMmbtus Fuel Costs (in cents (per Million Btu) (l)	GenerationType Generation Type (m)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

ENERGY STORAGE OPERATIONS (Large Plants)
Large Plants are plants of 10,000 Kw or more. In columns (a) (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location. In column (d), report Megawatt hours (MWH) purchased, generated, or received in exchange transactions for storage. In columns (e), (f) and (g) report MWHs delivered to the grid to support production, transmission and distribution. The amount reported in column (d) should include MWHs delivered/provided to a generator’s own load requirements or used for the provision of ancillary services. In columns (h), (i), and (j) report MWHs lost during conversion, storage and discharge of energy. In column (k) report the MWHs sold. In column (l), report revenues from energy storage operations. In a footnote, disclose the revenue accounts and revenue amounts related to the income generating activity. In column (m), report the cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. In columns (n) and (o), report fuel costs for storage operations associated with self-generated power included in Account 501 and other costs associated with self-generated power. In columns (q), (r) and (s) report the total project plant costs including but not exclusive of land and land rights, structures and improvements, energy storage equipment, turbines, compressors, generators, switching and conversion equipment, lines and equipment whose primary purpose is to integrate or tie energy storage assets into the power grid, and any other costs associated with the energy storage project included in the property accounts listed.
Line No.	Name of the Energy Storage Project (a)	Functional Classification (b)	Location of the Project (c)	MWHs (d)	MWHs delivered to the grid to support Production (e)	MWHs delivered to the grid to support Transmission (f)	MWHs delivered to the grid to support Distribution (g)	MWHs Lost During Conversion, Storage and Discharge of Energy Production (h)	MWHs Lost During Conversion, Storage and Discharge of Energy Transmission (i)	MWHs Lost During Conversion, Storage and Discharge of Energy Distribution (j)	MWHs Sold (k)	Revenues from Energy Storage Operations (l)	Power Purchased for Storage Operations (555.1) (Dollars) (m)	Fuel Costs from associated fuel accounts for Storage Operations Associated with Self- Generated Power (Dollars) (n)	Other Costs Associated with Self-Generated Power (Dollars) (o)	Account for Project Costs (p)	Production (Dollars) (q)	Transmission (Dollars) (r)	Distribution (Dollars) (s)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35	TOTAL			0	0	0	0	0	0	0	0	0	0	0	0		0	0	0

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

ENERGY STORAGE OPERATIONS (Small Plants)
Small Plants are plants less than 10,000 Kw. In columns (a), (b) and (c) report the name of the energy storage project, functional classification (Production, Transmission, Distribution), and location. In column (d), report project plant cost including but not exclusive of land and land rights, structures and improvements, energy storage equipment and any other costs associated with the energy storage project. In column (e), report operation expenses excluding fuel, (f), maintenance expenses, (g) fuel costs for storage operations and (h) cost of power purchased for storage operations and reported in Account 555.1, Power Purchased for Storage Operations. If power was purchased from an affiliated seller specify how the cost of the power was determined. If any other expenses, report in column (i) and footnote the nature of the item(s).
					BALANCE AT BEGINNING OF YEAR
Line No.	Name of the Energy Storage Project (a)	Functional Classification (b)	Location of the Project (c)	Project Cost (d)	Operations (Excluding Fuel used in Storage Operations) (e)	Maintenance (f)	Cost of fuel used in storage operations (g)	Account No. 555.1, Power Purchased for Storage Operations (h)	Other Expenses (i)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36	TOTAL			0	0	0	0	0	0

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

TRANSMISSION LINE STATISTICS
Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132 kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage. If required by a State commission to report individual lines for all voltages, do so but do not group totals for each voltage under 132 kilovolts. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not report substation costs and expenses on this page. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower; or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of construction by the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from the remainder of the line. Report in columns (f) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which is reported for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Report pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses with respect to such structures are included in the expenses reported for the line designated. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote if you do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report the pole miles of the primary structure in column (f) and the pole miles of the other line(s) in column (g). Designate any transmission line or portion thereof for which the respondent is not the sole owner. If such property is leased from another company, give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, for which the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining the arrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharing expenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, or other party is an associated company. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how determined. Specify whether lessee is an associated company. Base the plant cost figures called for in columns (j) to (l) on the book cost at end of year.
	DESIGNATION		VOLTAGE (KV) - (Indicate where other than 60 cycle, 3 phase)			LENGTH (Pole miles) - (In the case of underground lines report circuit miles)				COST OF LINE (Include in column (j) Land, Land rights, and clearing right-of-way)			EXPENSES, EXCEPT DEPRECIATION AND TAXES
Line No.	TransmissionLineStartPoint From	TransmissionLineEndPoint To	OperatingVoltageOfTransmissionLine Operating	DesignedVoltageOfTransmissionLine Designated	SupportingStructureOfTransmissionLineType Type of Supporting Structure	LengthForStandAloneTransmissionLines On Structure of Line Designated	LengthForTransmissionLinesAggregatedWithOtherStructures On Structures of Another Line	NumberOfTransmissionCircuits Number of Circuits	SizeOfConductorAndMaterial Size of Conductor and Material	CostOfLandAndLandRightsTransmissionLines Land	ConstructionAndOtherCostsTransmissionLines Construction Costs	OverallCostOfTransmissionLine Total Costs	OperatingExpensesOfTransmissionLine Operation Expenses	MaintenanceExpensesOfTransmissionLine Maintenance Expenses	RentExpensesOfTransmissionLine Rents	OverallExpensesOfTransmissionLine Total Expenses
	(a)	(b)	(c)	(d)	(e)	(f)	(g)	(h)	(i)	(j)	(k)	(l)	(m)	(n)	(o)	(p)
1													8,255,052	2,916,898	143,487	11,315,437
2	BAXTER WILSON	GRAND GULF 500 - [5620]	500	500	Steel Tower	21.46	0.00	1	954 ACSR
3	BAXTER WILSON	PERRYVILLE 500 - [55003]	500	500	Steel Tower	1.46	0.00	1	3070 AACSR
4	BAXTER WILSON	RAY BRASWELL 500 - [6880]	500	500	Steel Tower	30.10	5.44	2	954 ACSR
5	BOGALUSA 500	FRANKLIN EHV - [5521]	500	500	Steel Tower	51.38	0.00	1	954 ACSR
6	CHOCTAW	FRENCH CAMP 500 - [5014]	500	500	Steel Pole	0.81	0.00	1	954 ACSR
7	FRANKLIN	GRAND GULF 500 - [5640]	500	500	Steel Tower	43.46	0.00	1	954 ACSR
8	FRANKLIN	RAY BRASWELL 500 - [6980]	500	500	Steel Tower	58.30	0.00	1	954 ACSR
9	MCADAMS	LAKEOVER 500 - [55008,55016]	500	500	Steel Tower	57.44	0.00	1	954 ACSR
10	MCKNIGHT	FRANKLIN 500 - [6980]	500	500	Steel Tower	38.36	0.00	1	[3]-954 ACSR
11	RAY BRASWELL	LAKEOVER 500 - [55011]	500	500	Steel Tower	19.15	3.35	2	954 ACSR
12	WOLF CREEK	CHOCTAW 500 - [5015]	500	500	Steel Tower	0.11	0.00	1	954 ACSR
13	WOLF CREEK	FRENCH CAMP 500 - [55013]	500	500	Steel Tower	0.83	0.00	1	954 ACSR
14	WOLF CREEK	MCADAMS 500 - [55001]	500	500	Steel Tower	24.21	0.00	1	954 ACSR
15	Total 500kV									5,483,196	65,890,633	71,373,829
16	BATESVILLE	SIX MILE LAKE 230 kV - [52301]	230	230	Wood H-Frame	28.58	0.00	1	1272 ACSR
17	CANTON SOUTH	ENDRIS 230 - [52348]	230	230	Steel Pole	2.26	1.80	2	1272 ACSR
18	CATLETT	YANDELL RD 230 - [2343]	230	230	Steel Pole	10.77	1.69	2	1272 ACSR
19	CATLETT	SOUTH CANTON 230 - [2392]	230	230	Steel Pole	3.71	0.00	1	1272 ACSR
20	CATLETT	TINNIN RD 230 - [5112]	230	230	Steel Pole	23.61	1.68	2	1272 ACSR
21	CATLETT	VIRLILIA LN 1 - [52349]	230	230	Steel Pole	0.21	0.00	1	1272 ACSR
22	CATLETT	VIRLILIA LN 2 - [52350]	230	230	Steel Pole	0.21	0.00	1	1272 ACSR
23	ENDRIS	YANDELL ROAD 230 - [52314]	230	230	Steel Pole	3.85	1.76	2	1272 ACSR
24	FREEPORT	HORN LAKE 230 - [5942]	230	230	Concrete Pole	3.81	0.00	1	954 ACSR
25	GERALD ANDRUS	LAKE VILLAGE BAGBY 230 - [5540]	230	230	Wood H-Frame	3.59	0.00	1	1534.4 ACAR
26	GERALD ANDRUS	INDIANOLA 230 - [5580]	230	230	Wood H-Frame	25.30	8.38	2	1272 ACSR
27	GETWELL	BYHALA 230 - [2341]	230	230	Steel Pole	5.88	0.00	1	1272 ACSR
28	GETWELL	TWINKLETOWN 230 - [5007]	230	230	Steel Pole	19.14	1.40	2	1272 ACSR
29	HORN LAKE	GETWELL 230 - [6186]	230	230	Concrete Pole	3.80	4.77	2	1272 ACSR
30	INDIANOLA	TILLATOBA 230 - [6020]	230	230	Wood H-Frame	56.36	0.00	1	1272 ACSR
31	LAKEOVER	LUCKNEY 230 - [52311]	230	230	Steel Tower	14.40	8.40	2	1272 ACSR
32	LAKEOVER	YANDELL RD 230 - [2335]	230	230	Steel Tower	8.14	10.16	2	1272 ACSR
33	LAKEOVER	HINDS2 BLACKSTART GT3 - [2342]	230	230	Steel Pole	0.70	0.00	1	954 ACSR
34	LAKEOVER	REX BROWN (EAST) 230 - [6184]	230	230	Steel Tower	0.18	1.56	2	1272 ACSR
35	LAKEOVER	REX BROWN (WEST) 230 - [6183]	230	230	Steel Tower	0.18	1.57	2	1272 ACSR
36	LUCKNEY	RANKIN 230 - [6298]	230	230	Steel Pole	13.47	0.00	1	1272 ACSR
37	MCADAMS	ATTALA 230 - [6415]	230	230	Steel Tower	1.17	0.00	1	1272 ACSR
38	MCADAMS	INDIANOLA 230 - [6410]	230	230	Wood H-Frame	67.53	0.00	1	1272 ACSR
39	MCADAMS	PICKENS 230 - [6416]	230	230	Wood H-Frame	16.18	0.00	1	954 ACSR
40	RAY BRASWELL	S JACKSON 230 - [7370]	230	230	Concrete Pole	0.23	9.22	2	1272 ACSR
41	RAY BRASWELL	SOUTH JACKSON 230 - [7375]	230	230	Steel Tower	2.58	10.95	2	1272 ACSR
42	RAY BRASWELL	NORREL 230 - [2340]	230	230	Steel Pole	4.14	3.21	2	1272 ACSR
43	RAY BRASWEL	REX BROWN 230 - [7100]	230	230	Wood H-Frame	9.20	0.00	1	1272 ACSS
44	RITCHIE	MOON LAKE 230 - [6320]	230	230	Wood H-Frame	6.80	0.00	1	1947.5 ACSR
45	RITCHIE	TUNICA 230 - [7490]	230	230	Wood H-Frame	21.36	0.00	1	1947.5 ACSR
46	SIX MILE LAKE	MOON LAKE SS 230 kV - [52347]	230	230	Wood H-Frame	4.59	0.00	1	1272 ACSR
47	SOUTH CANTON	RAGSDALE 230 LN 1 - [5271]	230	230	Steel Pole	0.24	1.29	2	1272 ACSR
48	SOUTH CANTON	RAGSDALE 230 LN 2 - [5271]	230	230	Steel Pole	0.26	1.29	2	1272 ACSR
49	SOUTH CANTON	PICKENS 230 - [5270,6185]	230	230	Wood H-Frame	26.05	1.93	2	1272 ACSR
50	SOUTH JACKSON	RANKIN 230 - [7350]	230	230	Steel Pole	2.39	15.33	2	1272 ACSR
51	TILLATOBA	BATESVILLE 230 - [5840]	230	230	Concrete Pole	27.22	0.00	1	1780 ACSR
52	TILLATOBA	SOUTH GRENADA 230 - [2337]	230	230	Steel Pole	3.24	15.98	2	1272 ACSR
53	TINNIN RD	GERALD ANDRUS 230 - [52304,52391]	230	230	Wood H-Frame	70.50	8.38	2	1272 ACSR
54	TINNIN RD	NORREL 230 - [2339]	230	230	Steel Pole	6.91	0.00	1	1272 ACSR
55	TUNICA	TWINKLETOWN 230 - [5525]	230	230	Wood H-Frame	21.09	2.51	2	1272 ACSR
56	TWINKLETOWN	FREEPORT 230 - [5525]	230	230	Wood H-Frame	8.30	0.00	1	1272 ACSR
57	Total 230kV									43,119,446	229,950,035	273,069,481
58	HORN LAKE	ALLEN S 161 - [5960]	161	161	Steel Pole	5.86	0.00	1	954 ACSS
59	Total 161kV									9,982	397,075	407,057
60	Total 115kV					1,885.50	135.49			43,825,435	720,243,408	764,068,843
36	TOTAL					2,766.56	257.54	78		92,438,059	1,016,481,151	1,108,919,210	8,255,052	2,916,898	143,487	11,315,437

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

TRANSMISSION LINES ADDED DURING YEAR
Report below the information called for concerning Transmission lines added or altered during the year. It is not necessary to report minor revisions of lines. Provide separate subheadings for overhead and under- ground construction and show each transmission line separately. If actual costs of competed construction are not readily available for reporting columns (l) to (o), it is permissible to report in these columns the costs. Designate, however, if estimated amounts are reported. Include costs of Clearing Land and Rights-of-Way, and Roads and Trails, in column (l) with appropriate footnote, and costs of Underground Conduit in column (m). If design voltage differs from operating voltage, indicate such fact by footnote; also where line is other than 60 cycle, 3 phase, indicate such other characteristic.
	LINE DESIGNATION			SUPPORTING STRUCTURE		CIRCUITS PER STRUCTURE		CONDUCTORS				LINE COST
Line No.	TransmissionLineStartPoint From	TransmissionLineEndPoint To	LengthOfTransmissionLineAdded Line Length in Miles	SupportingStructureOfTransmissionLineType Type	AverageNumberOfSupportingStructuresOfTransmissionLinePerMiles Average Number per Miles	NumberOfTransmissionCircuitsPerStructurePresent Present	NumberOfTransmissionCircuitsPerStructureUltimate Ultimate	ConductorSize Size	ConductorSpecification Specification	ConductorConfigurationAndSpacing Configuration and Spacing	OperatingVoltageOfTransmissionLine Voltage KV (Operating)	CostOfLandAndLandRightsTransmissionLinesAdded Land and Land Rights	CostOfPolesTowersAndFixturesTransmissionLinesAdded Poles, Towers and Fixtures	CostOfConductorsAndDevicesTransmissionLinesAdded Conductors and Devices	Asset Retire. Costs	CostOfTransmissionLinesAdded Total	SupportingStructureConstructionType Construction
	(a)	(b)	(c)	(d)	(e)	(f)	(g)	(h)	(i)	(j)	(k)	(l)	(m)	(n)	(o)	(p)	(q)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44	TOTAL		0.00		0	0	0

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

SUBSTATIONS
Report below the information called for concerning substations of the respondent as of the end of the year. Substations which serve only one industrial or street railway customer should not be listed below. Substations with capacities of Less than 10 MVA except those serving customers with energy for resale, may be grouped according to functional character, but the number of such substations must be shown. Indicate in column (b) the functional character of each substation, designating whether transmission or distribution and whether attended or unattended. At the end of the page, summarize according to function the capacities reported for the individual stations in column (f). Show in columns (I), (j), and (k) special equipment such as rotary converters, rectifiers, condensers, etc. and auxiliary equipment for increasing capacity. Designate substations or major items of equipment leased from others, jointly owned with others, or operated otherwise than by reason of sole ownership by the respondent. For any substation or equipment operated under lease, give name of lessor, date and period of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership or lease, give name of co-owner or other party, explain basis of sharing expenses or other accounting between the parties, and state amounts and accounts affected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated company.
		Character of Substation		VOLTAGE (In MVa)						Conversion Apparatus and Special Equipment
Line No.	SubstationNameAndLocation Name and Location of Substation (a)	SubstationCharacterDescription Transmission or Distribution (b)	SubstationCharacterAttendedOrUnattended Attended or Unattended (b-1)	PrimaryVoltageLevel Primary Voltage (In MVa) (c)	SecondaryVoltageLevel Secondary Voltage (In MVa) (d)	TertiaryVoltageLevel Tertiary Voltage (In MVa) (e)	SubstationInServiceCapacity Capacity of Substation (In Service) (In MVa) (f)	NumberOfTransformersInService Number of Transformers In Service (g)	Number of Spare Transformers (h)	ConversionApparatusAndSpecialEquipmentType Type of Equipment (i)	NumberOfConversionApparatusAndSpecialEquipmentUnits Number of Units (j)	CapacityOfConversionApparatusAndSpecialEquipment Total Capacity (In MVa) (k)
1	AIRPORT/JACKSON	Distribution	Unattended	(a) 115.0	(b) 14.5		56.0	2	0
2	ATTALA	Distribution	Unattended	230.0	13.8		20.0	1	0
3	BELZONI	Distribution	Unattended	115.0	13.9		44.8	2	0
4	BOLTON	Distribution	Unattended	115.0	13.9		18.8	2	0
5	BOVINA	Distribution	Unattended	115.0	12.5		11.2	1	0
6	BOZEMAN ROAD	Distribution	Unattended	230.0	13.8		73.3	2	0
7	BRANDON	Distribution	Unattended	115.0	14.4		89.3	3	0
8	BRICKYARD	Distribution	Unattended	115.0	14.4		33.3	1	0
9	BROOKHAVEN	Distribution	Unattended	115.0	14.4		94.7	3	0
10	BROOKHAVEN/SOUTH	Distribution	Unattended	115.0	14.4		61.3	2	0
11	BYHALIA	Distribution	Unattended	230.0	12.5		40.0	1	0
12	BYRAM	Distribution	Unattended	115.0	14.5		66.9	2	0
13	CANTON	Distribution	Unattended	230.0	13.9		67.2	2	0
14	CANTON ROAD/JACKSON	Distribution	Unattended	115.0	14.5		66.9	2	0
15	CANTON/SOUTH	Distribution	Unattended	230.0	13.8		73.3	2	0
16	CARTHAGE (MS)	Distribution	Unattended	115.0	13.9		44.8	2	0
17	CATLETT	Distribution	Unattended	230.0	12.5		80.0	2	0
18	CENTREVILLE	Distribution	Unattended	115.0	13.9		40.0	2	0
19	CHARITY CHURCH/JACKSON	Distribution	Unattended	230.0	14.4		66.9	2	0
20	CHARLESTON	Distribution	Unattended	115.0	13.9		44.8	2	0
21	CHURCH ROAD	Distribution	Unattended	230.0	14.4		40.0	1	0
22	CLARKSDALE	Distribution	Unattended	115.0	13.8		40.0	2	0
23	CLEVELAND [MS]	Distribution	Unattended	115.0	13.9		84.0	3	0
24	CLEVELAND/SOUTH	Distribution	Unattended	115.0	13.9		56.0	2	0
25	CLINTON [MS]	Distribution	Unattended	115.0	14.5		50.4	2	0
26	CLINTON INDUSTRIAL	Distribution	Unattended	230.0	14.5		61.3	2	0
27	COLDWATER	Distribution	Unattended	115.0	13.8		66.6	2	0
28	COMO	Distribution	Unattended	115.0	13.9		20.0	2	0
29	COUNTRY CLUB/JACKSON	Distribution	Unattended	115.0	14.4		61.3	2	0
30	CRENSHAW	Distribution	Unattended	115.0	13.9		22.4	1	0
31	CRYSTAL SPRINGS	Distribution	Unattended	115.0	13.9		44.8	2	0
32	DESOTO	Distribution	Unattended	115.0	14.5		56.0	2	0
33	DREW [MS]	Distribution	Unattended	115.0	13.9		34.9	2	0
34	DURANT	Distribution	Unattended	115.0	14.5		32.5	2	0
35	EDWARDS	Distribution	Unattended	115.0	13.8		32.5	2	0
36	ELLIOTT	Distribution	Unattended	115.0	14.4		55.7	2	0
37	ELTON RD	Distribution	Unattended	115.0	13.9		20.0	1	0
38	ENID	Distribution	Unattended	230.0	14.4		20.0	1	0
39	FANNIN ROAD	Distribution	Unattended	115.0	13.9		50.4	2	0
40	FAYETTE	Distribution	Unattended	115.0	13.8		20.0	1	0
41	FERNWOOD	Distribution	Unattended	115.0	13.9		44.8	2	0
42	FLORA	Distribution	Unattended	115.0	14.5		68.0	2	0
43	FLORENCE	Distribution	Unattended	115.0	14.4		61.3	2	0
44	FLOWERS	Distribution	Unattended	115.0	13.8		40.0	2	0
45	FLOWOOD	Distribution	Unattended	115.0	14.5		66.7	2	0
46	FONDREN/JACKSON	Distribution	Unattended	115.0	14.5		78.1	3	0
47	FOREST HILL/JACKSON	Distribution	Unattended	115.0	13.9		56.0	2	0
48	GALLATIN STREET/JACKSON	Distribution	Unattended	115.0	13.9		56.0	2	0
49	GALLMAN	Distribution	Unattended	115.0	13.9		44.8	2	0
50	GEORGETOWN [MS]	Distribution	Unattended	115.0	13.8		12.5	1	0
51	GETWELL	Distribution	Unattended	230.0	13.8		80.0	2	0
52	GLEN ALLAN	Distribution	Unattended	115.0	13.9		5.0	1	0
53	GLOSTER	Distribution	Unattended	115.0	14.4		74.9	3	0
54	GRAND GULF DISTRIBUTION	Distribution	Unattended	115.0	14.5		20.0	1	0
55	GRANTS FERRY	Distribution	Unattended	230.0	13.9		70.9	2	0
56	GREENBROOK	Distribution	Unattended	115.0	14.4		94.7	3	0
57	GREENVILLE	Distribution	Unattended	115.0	13.9		56.0	2	0
58	GREENVILLE/EAST	Distribution	Unattended	115.0	13.9		42.4	2	0
59	GREENVILLE/INDUSTRIAL	Distribution	Unattended	115.0	13.9		50.4	2	0
60	GREENVILLE/MIDTOWN	Distribution	Unattended	115.0	13.9		44.8	2	0
61	GREENVILLE/NORTH	Distribution	Unattended	115.0	14.5		94.6	3	0
62	GREENVILLE/SOUTHEAST	Distribution	Unattended	115.0	13.9		28.0	1	0
63	GREENWOOD	Distribution	Unattended	115.0	13.9		44.8	2	0
64	GRENADA	Distribution	Unattended	115.0	13.9		78.4	3	0
65	GRENADA/SOUTH	Distribution	Unattended	230.0	13.9		50.4	2	0
66	HAINING ROAD	Distribution	Unattended	115.0	13.9		50.4	2	0
67	HAZLEHURST	Distribution	Unattended	115.0	13.9		50.4	2	0
68	HENDERSON ROAD	Distribution	Unattended	230.0	13.8		80.0	2	0
69	HERNANDO	Distribution	Unattended	115.0	13.9		83.2	2	0
70	HOLLANDALE	Distribution	Unattended	115.0	13.9		50.4	2	0
71	HORN LAKE	Distribution	Unattended	230.0	14.5		100.2	3	0
72	HOY ROAD	Distribution	Unattended	230.0	13.9		67.2	2	0
73	INDIANOLA 115 SUB	Distribution	Unattended	115.0	13.9		56.0	2	0
74	INVERNESS	Distribution	Unattended	115.0	13.8		40.0	2	0
75	JACKSON/EAST	Distribution	Unattended	115.0	13.9		100.5	3	0
76	JACKSON/NORTH	Distribution	Unattended	115.0	13.9		72.8	3	0
77	JACKSON/NORTHEAST	Distribution	Unattended	115.0	13.9		62.4	3	0
78	JACKSON/NORTHWEST	Distribution	Unattended	115.0	14.5		56.0	2	0
79	JACKSON/SOUTH	Distribution	Unattended	230.0	13.9		67.2	2	0
80	JACKSON/SOUTHWEST	Distribution	Unattended	115.0	13.9		44.8	2	0
81	JACKSON/TREATMENT PLANT	Distribution	Unattended	115.0	4.2		12.5	1	0
82	JACKSON/WATERWORKS	Distribution	Unattended	14.0
83	JACKSON/WEST	Distribution	Unattended	115.0	13.9		56.0	2	0
84	JOHNS MANVILLE	Distribution	Unattended	115.0	14.4		61.3	2	0
85	JONESTOWN	Distribution	Unattended	115.0	13.8		10.5	1	0
86	KINGSWOOD/JACKSON	Distribution	Unattended	115.0	13.9		56.0	2	0
87	KOSCIUSKO	Distribution	Unattended	115.0	14.4		68.0	2	0
88	LAKE CASTLE	Distribution	Unattended	230.0	14.5		66.7	2	0
89	LARSON ST/JACKSON	Distribution	Unattended	115.0	14.5		33.6	1	0
90	LELAND	Distribution	Unattended	115.0	14.5		45.8	2	0
91	LEXINGTON	Distribution	Unattended	115.0	13.9		42.4	2	0
92	LIBERTY	Distribution	Unattended	115.0	13.9		30.0	2	0
93	LIVINGSTON ROAD/JACKSON	Distribution	Unattended	115.0	14.4		62.4	2	0
94	LUCKNEY	Distribution	Unattended	230.0	13.9		67.2	2	0
95	LULA	Distribution	Unattended	115.0	13.9		20.0	1	0
96	MADISON	Distribution	Unattended	115.0	13.8		80.0	2	0
97	MAGEE	Distribution	Unattended	115.0	14.5		50.4	2	0
98	MARKS	Distribution	Unattended	115.0	13.9		44.8	2	0
99	MCCOMB	Distribution	Unattended	115.0	13.9		61.3	2	0
100	MCCOMB/WEST	Distribution	Unattended	115.0	13.9		50.4	2	0
101	MEADVILLE	Distribution	Unattended	115.0	13.9		20.0	1	0
102	MEDICAL CENTER/JACKSON	Distribution	Unattended	115.0	13.9		67.2	2	0
103	MENDENHALL	Distribution	Unattended	115.0	14.5		66.6	2	0
104	MIAMI STREET/JACKSON	Distribution	Unattended	115.0	14.4		33.3	1	0
105	MIDNIGHT	Distribution	Unattended	115.0	13.9		27.4	2	0
106	MILL STREET	Distribution	Unattended	115.0	13.8		80.0	2	0
107	MONUMENT STREET/JACKSON	Distribution	Unattended	115.0	14.5		76.0	3	0
108	MOORHEAD	Distribution	Unattended	115.0	14.5		48.0	2	0
109	MORTON	Distribution	Unattended	115.0	14.4		33.3	1	0
110	NATCHEZ	Distribution	Unattended	115.0	14.4		61.3	2	0
111	NATCHEZ/INDUSTRIAL PARK	Distribution	Unattended	115.0	14.5		55.7	2	0
112	NATCHEZ/SOUTH	Distribution	Unattended	115.0	13.9		61.3	2	0
113	NESBIT	Distribution	Unattended	115.0	14.4		55.7	2	0
114	NEW HEBRON	Distribution	Unattended	115.0	13.8		10.5	1	0
115	NORTHPARK	Distribution	Unattended	230.0	14.4		66.3	2	0
116	NORTHSIDE DRIVE/JACKSON	Distribution	Unattended	230.0	13.9		56.0	2	0
117	PELAHATCHIE	Distribution	Unattended	115.0	14.5		22.4	1	0
118	PICKENS	Distribution	Unattended	230.0	13.9		28.5	2	0
119	PLUM POINT	Distribution	Unattended	115.0	14.5		106.7	3	0
120	PORT GIBSON	Distribution	Unattended	115.0	13.9		68.0	2	0
121	RALEIGH	Distribution	Unattended	115.0	13.9		30.5	2	0
122	RANKIN	Distribution	Unattended	230.0	14.4		61.3	2	0
123	RANKIN INDTRL./JACKSON	Distribution	Unattended	115.0	13.9		56.0	2	0
124	RAYMOND	Distribution	Unattended	115.0	14.5		56.0	2	0
125	REX BROWN 115 SWYD	Distribution	Unattended	115.0	13.8		40.0	1	0
126	RIDGELAND	Distribution	Unattended	115.0	14.5		66.6	2	0
127	ROBINSON ROAD/JACKSON	Distribution	Unattended	230.0	13.9		56.0	2	0
128	ROBINSONVILLE	Distribution	Unattended	230.0	34.5		163.3	6	0
129	ROLLING FORK	Distribution	Unattended	115.0	13.9		34.9	2	0
130	ROSEDALE [MS]	Distribution	Unattended	115.0	13.9		34.9	2	0
131	ROXIE	Distribution	Unattended	115.0	14.4		10.5	1	0
132	RULEVILLE	Distribution	Unattended	115.0	13.9		42.4	2	0
133	SARDIS	Distribution	Unattended	115.0	13.8		40.0	2	0
134	SCHLATER	Distribution	Unattended	115.0	13.9		21.9	2	0
135	SENATOBIA	Distribution	Unattended	115.0	14.4		73.3	2	0
136	SHELBY	Distribution	Unattended	115.0	13.9		20.9	2	0
137	SILVER CREEK	Distribution	Unattended	115.0	13.9		50.4	2	0
138	SNOWDEN PARK	Distribution	Unattended	115.0	13.9		80.0	2	0
139	SPENCER POTASH	Distribution	Unattended	115.0	13.9		22.4	1	0
140	SPRING RIDGE ROAD	Distribution	Unattended	115.0	13.9		33.6	1	0
141	STAR	Distribution	Unattended	115.0	13.9		22.5	2	0
142	STRINGTOWN	Distribution	Unattended	115.0	13.9		12.5	1	0
143	SUNNYBROOK	Distribution	Unattended	115.0	13.8		40.0	1	0
144	TERRY	Distribution	Unattended	115.0	13.8		51.9	2	0
145	TINNIN ROAD	Distribution	Unattended	230.0	13.8		40.0	1	0
146	TUNICA	Distribution	Unattended	115.0	13.9		22.4	1	0
147	TWINKLETOWN	Distribution	Unattended	230.0	14.4		33.3	1	0
148	TYLERTOWN	Distribution	Unattended	115.0	13.9		37.5	3	0
149	UTICA	Distribution	Unattended	115.0	13.9		30.5	2	0
150	VICKSBURG	Distribution	Unattended	115.0	13.9		42.4	2	0
151	VICKSBURG/EAST	Distribution	Unattended	115.0	13.9		42.4	2	0
152	VICKSBURG/NORTH	Distribution	Unattended	115.0	13.9		70.4	3	0
153	VICKSBURG/OPENWOOD	Distribution	Unattended	115.0	13.8		73.3	2	0
154	VICKSBURG/SOUTH	Distribution	Unattended	115.0	13.9		42.4	2	0
155	VICKSBURG/SOUTHEAST	Distribution	Unattended	115.0	13.9		28.0	1	0
156	VICKSBURG/WEST	Distribution	Unattended	115.0	14.4		53.0	2	0
157	WALLS	Distribution	Unattended	115.0	13.9		9.4	1	0
158	WEBB	Distribution	Unattended	115.0	13.9		16.9	2	0
159	WESSON	Distribution	Unattended	115.0	14.5		28.0	1	0
160	WHITFIELD	Distribution	Unattended	115.0	13.9		22.4	1	0
161	WINONA	Distribution	Unattended	115.0	13.9		55.4	2	0
162	WOODVILLE [MS]	Distribution	Unattended	115.0	13.9		12.5	1	0
163	WYNNDALE	Distribution	Unattended	115.0	13.8		80.0	2	0
164	YANDELL RD	Distribution	Unattended	230.0	13.9		100.3	3	0
165	YAZOO CITY SS	Distribution	Unattended	115.0	13.9		12.5	1	0
166	ATTALA	Transmission	Unattended	230.0	120.0	(c) 13.8	391.8	1	0
167	ATTALA PLANT	Transmission	Unattended	500.0
168	BATESVILLE [MS]	Transmission	Unattended	230.0	120.0	13.9	391.8	1	0
169	BAXTER WILSON SES SWYD	Transmission	Unattended	500.0	115.0		1176.0	2	0
170	BEECH GROVE SS	Transmission	Unattended	115.0
171	BOWLING GREEN SS	Transmission	Unattended	115.0
172	CHOCTAW	Transmission	Unattended	500.0
173	DELTA SWYD	Transmission	Unattended	115.0
174	ELLIOTT SS	Transmission	Unattended	115.0
175	ENDRIS	Transmission	Unattended	230.0
176	FRANKLIN EHV	Transmission	Unattended	500.0	115.0	13.8	1120.0	2	0
177	FREEPORT	Transmission	Unattended	500.0	230.0	13.9	975.0	1	0
178	GERALD ANDRUS SES SWYD	Transmission	Unattended	230.0	120.0	13.9	392.0	1	0
179	GETWELL	Transmission	Unattended	230.0	115.0	13.8	392.0	1	0
180	GRAND GULF TRANSMISSION	Transmission	Unattended	500.0
181	GRENADA/SOUTH	Transmission	Unattended	230.0	115.0		500.0	1	0
182	HARPER	Transmission	Unattended	115.0
183	HORN LAKE	Transmission	Unattended	230.0	161.0	13.8	1027.0	3	0
184	INDIANOLA 230/115 SUB	Transmission	Unattended	230.0	120.0		391.8	1	0
185	JACKSON/SOUTH	Transmission	Unattended	230.0	120.0	13.9	391.8	1	0
186	JONESTOWN SS	Transmission	Unattended	115.0
187	LAKEOVER EHV	Transmission	Unattended	500.0	230.0		1215.0	2	0
188	MCADAMS EHV	Transmission	Unattended	500.0	230.0		1500.0	2	0
189	MERCHANT ROAD	Transmission	Unattended	115.0
190	MINTER CITY SS	Transmission	Unattended	115.0
191	MOON LAKE SS	Transmission	Unattended	230.0
192	NATCHEZ SWYD	Transmission	Unattended	115.0
193	NORTHPARK	Transmission	Unattended	230.0	115.0	13.8	400.0	1	0
194	PICKENS	Transmission	Unattended	230.0	120.0	13.9	391.8	1	0
195	RANKIN	Transmission	Unattended	230.0	120.0	13.9	391.8	1	0
196	RAY BRASWELL EHV	Transmission	Unattended	500.0	230.0	13.9	2073.0	4	0
197	REX BROWN 230 SWYD	Transmission	Unattended	230.0	120.0	13.9	391.8	1	0
198	ROUND LAKE	Transmission	Unattended	115.0
199	SHELBY SS	Transmission	Unattended	115.0
200	SIX MILE LAKE	Transmission	Unattended	230.0
201	TILLATOBA	Transmission	Unattended	230.0	120.0	13.9	391.8	1	0
202	TUNICA 230/115 SUB	Transmission	Unattended	230.0	120.0		391.8	1	0
203	VALLEY HILL	Transmission	Unattended	115.0
204	VICKSBURG/EAST SS	Transmission	Unattended	115.0
205	WOLF CREEK	Transmission	Unattended	500.0
206	YAZOO CITY MUNICIPAL SS	Transmission	Unattended	115.0
207	TotalDistributionSubstationMember											165
208	TotalGenerationSubstationMember											0
209	TotalTransmissionSubstationMember											41
210	Total											206

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: PrimaryVoltageLevel

Voltage in columns (c), (d), and (e) is reported in KV and not MVa.

(b) Concept: SecondaryVoltageLevel

Voltage in columns (c), (d), and (e) is reported in KV and not MVa.

(c) Concept: TertiaryVoltageLevel

Voltage in columns (c), (d), and (e) is reported in KV and not MVa.

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES
Report below the information called for concerning all non-power goods or services received from or provided to associated (affiliated) companies. The reporting threshold for reporting purposes is $250,000. The threshold applies to the annual amount billed to the respondent or billed to an associated/affiliated company for non-power goods and services. The good or service must be specific in nature. Respondents should not attempt to include or aggregate amounts in a nonspecific category such as "general". Where amounts billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote.
Line No.	Description of the Good or Service (a)	Name of Associated/Affiliated Company (b)	Account(s) Charged or Credited (c)	Amount Charged or Credited (d)
1	Non-power Goods or Services Provided by Affiliated
2	(a) See footnote for schedule details
3	(b) See footnote for allocation method details
19
20	Non-power Goods or Services Provided for Affiliated
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42

Name of Respondent:

Entergy Mississippi, LLC

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

04/15/2025

Year/Period of Report

End of:

2024

/

Q4

FOOTNOTE DATA

(a) Concept: DescriptionOfNonPowerGoodOrService

Non-power goods or services received from or provided to associated (affiliated) companies are reported in the schedule below by type of category, where the amount charged or credited from or to each affiliate is equal to or greater than the $250,000 threshold.

Line No.

Description of the Non-Power Good or Service

Name of Associated/Affiliated Company

Account Charged or Credited

Amount Charged or Credited

(a)

(b)

(c)

(d)

1

Non-power Goods or Services Provided by Affiliate

2

Support - Corporate

Entergy Services, LLC

107000, 108220, 108230, 118001, 163000, 174101, 174200, 181000, 181CPD, 183000, 183KSL, 184001, 1840FS, 228100, 228400, 4031AM, 408110, 408155, 408158, 426100, 426400, 426500, 430000, 431000, 454000, 500000, 506000, 510000, 513000, 514000, 546000, 549000, 551000, 560000, 561200, 561300, 561500, 563000, 566000, 568000, 580000, 581000, 583000, 584000, 586000, 588000, 590000, 592000, 593000, 596000, 597000, 598000, 901000, 902000, 903001, 903002, 904000, 905000, 907000, 908000, 909000, 910000, 912000, 916000, 920000, 921000, 922000, 923000, 924000, 925000, 926000, 926NS1, 928000, 930100, 930200, 931000, 935000

76,386,424

3

Support - Finance and Accounting

Entergy Services, LLC

107000, 108220, 163000, 174101, 181CPD, 183000, 183KSL, 184001, 1840FS, 228100, 408110, 419000, 426100, 426300, 426400, 426500, 500000, 514000, 560000, 568000, 580000, 586000, 588000, 901000, 902000, 903001, 903002, 905000, 912000, 913000, 920000, 921000, 922000, 923000, 924000, 925000, 925INS, 926000, 928000, 930100, 930200, 931000

16,736,537

4

Support - Power Generation

Entergy Services, LLC

107000, 108220, 163000, 174101, 174200, 183000, 183KSL, 228400, 408110, 426500, 500000, 506000, 507000, 510000, 513000, 514000, 546000, 549000, 551000, 560000, 561200, 5612BA, 566000, 580000, 588000, 589000, 920000, 921000, 922000, 923000, 926000, 928000, 930200

9,397,001

5

Support - Information Technology

Entergy Services, LLC

107000, 108220, 163000, 174101, 174200, 184001, 228100, 408110, 426400, 454000, 500000, 506000, 514000, 549000, 560000, 566000, 568000, 573000, 580000, 588000, 589000, 598000, 903001, 910000, 920000, 921000, 922000, 923000, 926000, 930100, 930200, 931000, 935000

29,611,719


6	Support - Power Delivery	Entergy Services, LLC	107000, 108220, 108230, 163000, 174101, 174200, 183000, 183KSL, 184001, 1840FS, 184EST, 228100, 228400, 408110, 426400, 426500, 500000, 506000, 507000, 514000, 546000, 549000, 556000, 557000, 560000, 561200, 5612BA, 561300, 561500, 565400, 566000, 567000, 568000, 569000, 569200, 573000, 580000, 581000, 583000, 584000, 586000, 588000, 589000, 590000, 591000, 592000, 593000, 596000, 597000, 598000, 901000, 902000, 903001, 903002, 905000, 907000, 908000, 909000, 910000, 912000, 916000, 920000, 921000, 922000, 923000, 925000, 926000, 928000, 930100, 930200, 931000	47,357,789
7	Support - President/CEO	Entergy Services, LLC	107000, 174101, 183KSL, 184001, 408110, 426100, 426500, 514000, 560000, 566000, 568000, 580000, 588000, 903001, 905000, 907000, 908000, 909000, 910000, 911000, 912000, 913000, 916000, 920000, 921000, 922000, 923000, 926000, 930100, 930200, 931000, 935000	6,899,823
8	Loaned Labor and Associated Loaders	Entergy Arkansas, LLC	107000, 108230, 152000, 408110, 502000, 506000, 512000, 513000, 514000, 549000, 586000, 587000, 592000, 593000, 594000, 597000, 598000, 902000, 903001, 926000, 926NS1	169,342
9	Storm Support	Entergy Arkansas, LLC	107000, 174101	459,387
10	Loaned Labor and Associated Loaders	Entergy Louisiana, LLC	107000, 174200, 408110, 502000, 506000, 512000, 513000, 586000, 587000, 588000, 593000, 594000, 596000, 903001, 920000, 922000, 926000, 926NS1, 912000	265,224
11	Storm Support	Entergy Louisiana, LLC	107000, 174101	32,842
12	Non-power Goods or Services Provided for Affiliate
13	Loaned Labor and Associated Loaders	Entergy Louisiana, LLC	107000, 174200, 228400, 408110, 549000, 553000, 580000, 583000, 587000, 588000, 592000, 593000, 594000, 596000, 598000, 878000, 887000, 902000, 903001, 926000, 926NS1	231,614
14	Storm Support	Entergy Louisiana, LLC	174101	792,882
15	Loaned Labor and Associated Loaders	Entergy Texas, Inc.	107000, 408110, 514000, 571000, 583000, 584000, 586000, 587000, 592000, 593000, 594000, 596000, 598000, 926000, 926NS1	60,386
16	Storm Support	Entergy Texas, Inc.	174101, 228100	1,393,230

(b) Concept: DescriptionOfNonPowerGoodOrService

Listed below are the allocation factors used to allocate costs to the affiliate.

Note: Where no allocation factor is provided for the non-power goods or services listed on Schedule 429, the costs associated with those goods and services were directly charged and not allocated.


Description of the Non-Power Good or Service			Cost Allocator(s)
Entergy Services, LLC
Support - Corporate			APPSUNIX, APPSUPAL, APTRNALL, ARTRNALL, ASSTSALL, ASSTSREG, ASTREGOP, BNKACCTA, CAPACCGT, CAPAOPCO, CAPXCOPC, COMCLAIM, CUSEGAMI, CUSEGXTX, CUSEOPCO, CUSTCALL, CUSTEGOP, DIRCTEMI, DSTLNALL, EMPLFRAN, EMPLOCSS, EMPLOFOS, EMPLOREG, EMPLOYAL, EMPLPRES, EMPLTRAN, EMPLUTOP, GENLDREG, GENLEDAL, GWHOPCPE, INSPREAL, ITSPENDA, LBRBILAL, LBRCOMUN, LBRCORPT, LBRFDPOL, LBRFINAN, LBRINFOR, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, MACCTALL, NETPPEAL, OWNISFI, PCNUMALL, PCNUMXNR, PKLOADAL, PRCHKALL, RADIOALL, RECDMGNT, SCDSPALL, SCFSPALL, SCLDTMLS, SCMATRAN, SCPSPALL, SCPSPXNC, SCRSPALL, SCTSPALL, SQFTALLC, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP, VEHCLFOS, VEHCLUSG
Support - Finance and Accounting			APPSUPAL, APTRNALL, ARTRNALL, ASSTSALL, ASSTSREG, BNKACCTA, CAPAOPCO, CAPXCOPC, CUSEGAMI, CUSEGXTX, CUSEOPCO, CUSTCALL, CUSTEGOP, CUSTEXTX, DIRCTEMI, EMPLOREG, EMPLOYAL, EMPLPRES, GENLDREG, GENLEDAL, INSPREAL, ITSPENDA, LBRBILAL, LBRCOMUN, LBRCORPT, LBRFDPOL, LBRFINAN, LBRINFOR, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, MACCTALL, NETPPEAL, OWNISFI, PKLOADAL, PRCHKALL, SCMATRAN, SCPSPALL, SCRSPALL, TRANSPND, TRSBLNOP, VEHCLFOS, VEHCLUSG
Support - Power Generation			APPSUPAL, ASSTSALL, ASSTSREG, CAPACCGT, CAPAOPCO, CAPXCOPC, CUSEGAMI, CUSEOPCO, CUSTEGOP, DIRCTEMI, EMPLFRAN, EMPLOYAL, GWHOPCPE, ITSPENDA, LBRBILAL, LBRCOMUN, LBRFDPOL, LBRFINAN, LBRSUPCN, LBRUTOPN, LVLSVCAL, MACCTALL, NETPPEAL, PCNUMALL, PKLOADAL, SCDSPALL, SCFSPALL, SCPSPALL, TELPHALL, TRANSPND, TRSBLNOP
Support - Information Technology			APPSMVSX, APPSUNIX, APPSUPAL, APPSWINT, APTRNALL, ASSTSALL, ASSTSREG, CAPACCGT, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTCALL, CUSTEGOP, DIRCTEMI, DSTLNALL, EMPLOYAL, GENLEDAL, GWHOPCPE, ITSPENDA, LBRBILAL, LBRCORPT, LBRINFOR, LBRLEGAL, MACCTALL, NETPPEAL, PCNUMALL, PCNUMXNR, PKLOADAL, PRCHKALL, RADIOALL, RECDMGNT, SCDSPALL, SCLDTMLS, SCPSPALL, SCRSPALL, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP, VEHCLUSG
Support - Power Delivery			APPSUPAL, APTRNALL, ASSTSALL, ASSTSREG, ASTREGOP, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTCALL, CUSTEGOP, DIRCTEMI, DSTLNALL, EMPLFRAN, EMPLOYAL, EMPLTRAN, GENLDREG, GENLEDAL, ITSPENDA, LBRBILAL, LBRCORPT, LBRFDPOL, LBRLEGAL, LBRSUPCN, LBRUTOPN, LVLSVCAL, MACCTALL, NETPPEAL, PCNUMALL, PCNUMXNR, PKLOADAL, PRCHKALL, RADIOALL, SCDSPALL, SCFSPALL, SCLDTMLS, SCPSPALL, SCRSPALL, SCTSPALL, SQFTALLC, TELPHALL, TRALINOP, TRANSPND, TRASUBOP, TRSBLNOP, VEHCLFOS, VEHCLUSG
Support - President/CEO			APPSUPAL, ASSTSALL, ASSTSREG, CAPAOPCO, CUSEGAMI, CUSEOPCO, CUSTCALL, CUSTEGOP, DIRCTEMI, DSTLNALL, EMPLOYAL, GENLEDAL, ITSPENDA, LBRFDPOL, LBRLEGAL, LBRUTOPN, MACCTALL, NETPPEAL, PCNUMALL, PKLOADAL, TRSBLNOP

Cost Allocator Descriptions


Cost Allocator	Cost Allocator Title	Cost Allocator Description
Entergy Services, LLC
APPSMVSX	Server and Mainframe Usage - MVS	Based on mainframe usage
APPSUNIX	Server and Mainframe Usage - UNIX	Based on the UNIX server usage
APPSUPAL	Server and Mainframe Usage - Composite	Based on a weighted composite of UNIX and NT servers and mainframe usage
APPSWINT	Server and Mainframe Usage - NTS	Based on WINTEL server usage
APTRNALL	Accounts Payable Transactions	Based on a twelve month number of accounts payable transactions processed
ARTRNALL	Accounts Receivable Invoices	Based on a twelve month number of accounts receivable transactions processed
ASSTSALL	Total Assets	Based on the total assets at period end
ASSTSREG	Total Assets - Regulated BU's	Based on total assets at period end for all regulated Business Units
ASTREGOP	Total Assets - Regulated BUs, excluding SERI	Based on total assets at period end for all regulated Business Units, excluding SERI
BNKACCTA	Bank Accounts	Based on the number of bank accounts at period end
CAPACCGT	System Capacity - CCGT	Based on the power level, in kilowatts, that could be achieved if all non-nuclear generating units were operating at maximum capability simultaneously (CCGT)
CAPAOPCO	System Capacity	Based on the power level, in kilowatts, that could be achieved if all non-nuclear generating units were operating at maximum capability simultaneously
CAPXCOPC	System Capacity - Excluding Coal and Nuclear	Based on the power level, in kilowatts, that could be achieved if all non-coal and non-nuclear generating units were operating at maximum capability simultaneously
COMCLAIM	Workers' Compensation Claims	Based on number of open workers' compensation claims
CUSEGAMI	Customers - AMI Only	Based on a twelve-month average number of electric-only, gas-only, and dual (electric and gas) customers derived from the number of gas-only customers provided by Gas Operations. This method should only be used to allocate Advanced Metering Infrastructure (AMI) deployment infrastructure expense. (Does not include meter hardware purchases)
CUSEGXTX	Electric and Gas Customers - Excluding ETI	Based on a twelve-month average number of electric and gas residential, commercial, industrial, government, municipal, and general business customers, excluding ETI
CUSEOPCO	Electric Customers	Based on a twelve-month average number of electric residential, commercial, industrial, government, and municipal customers
CUSTCALL	Customer Call Centers	Based on a twenty-four month average of customer calls
CUSTEGOP	Electric and Gas Customers	Based on a twelve-month average number of electric and gas residential, commercial, industrial, government, and municipal general business customers
CUSTEXTX	Electric Customers - Excluding ETI	Based on a twelve-month average number of electric residential, commercial, industrial, government, and municipal customers for EAI, ELA, EMI, and ENOI
DIRCTEMI	100% to EMI (BU M0000)	Bill 100% to Entergy Mississippi, Inc. (BU M0000)
DSTLNALL	Distribution Line Miles	Based on the number of miles of distribution lines
EMPLFRAN	Employees - Franchise Operations	Based on the number of full-time and part-time employees within Franchise Operations


EMPLOCSS	Employees - Customer Support Services	Based on the number of full-time and part-time employees within Customer Support Service
EMPLOFOS	Employees - Fossil Plant Operations	Based on the number of full-time and part-time employees within Fossil Plant Operations
EMPLOREG	Full-Time and Part-Time Employees - EAI, ELA, EMI, ENOI, SERI, ETI and ESI	Based on the number of full-time and part-time employees at period end for EAI, ELA, EMI, ENOI, SERI, ETI and ESI
EMPLOYAL	Full-Time and Part-Time Employees	Based on the number of full time and part time employees at period end
EMPLPRES	Employees - State President	Based on the number of full-time and part-time employees within State President Organizations
EMPLTRAN	Employees - Transmission	Based on the number of full-time and part-time employees within Transmission
EMPLUTOP	Employees - Utility Operations	Based on the number of full-time and part-time employees within Utility Operations
GENLDREG	General Ledger Transactions - Regulated Companies	Based on general ledger transactions for regulated companies
GENLEDAL	General Ledger Transactions	Based on the general ledger transactions
GWHOPCPE	GWH Energy Sales	Based on energy sales to ultimate customers
INSPREAL	Insurance Premiums	Based on non nuclear insurance premiums
ITSPENDA	Information Technology Total Spending	Based on Information Technology twelve-month total spending
LBRBILAL	ESL Labor Costs Billed	Based on total labor dollars billed to each Client Company by ESL
LBRCOMUN	ESL Labor Billed - Communications	Based on total labor dollars billed to each company by ESL for the Communications function
LBRCORPT	ESL Labor Billed - Corporate	Based on total labor dollars billed to each company by ESL for the Corporate function
LBRFDPOL	ESI Labor Billed - Federal Policy, Regulatory and Governmental Affairs	Based on total labor dollars billed to each company by ESI for the Federal Policy, Regulatory and Governmental Affairs function
LBRFINAN	ESL Labor Billed - Finance	Based on total labor dollars billed to each company by ESL for the Finance function
LBRINFOR	ESL Labor Billed - IT	Based on total labor dollars billed to each company by ESL for the IT function
LBRLEGAL	ESL Labor Billed - Legal	Based on total labor dollars billed to each company by ESL for the Legal function
LBRSUPCN	ESI Labor Billed - Supply Chain	Based on total labor dollars billed to each company by ESI for the Supply Chain function
LBRUTOPN	ESI Labor Billed - Utility Operations	Based on total labor dollars billed to each company by ESI for the Utility Operations function
LVLSVCAL	ESL Service Level	Based on ESL total billings to each Client Company
MACCTALL	Managed Accounts	Based on number of retail managed accounts
NETPPEAL	Net Property, Plant, and Equipment	Based on the net book value of all companies with property, plant and equipment - excluding natural gas and nuclear fuel
OWNISFI	Percentage Ownership - SFI	Based on the percentage ownership of SFI
PCNUMALL	Number of PC's	Based on the number of PC's within each Business Unit
PCNUMXNR	Number of PC's - Excluding Non-Regulated BU's	Based on the number of PC's within each regulated Business Unit at EAI, ELA, EMI, ENOI, SERI, ETI and ESI
PKLOADAL	Peak Load Ratio	Based on the ratio of each Client Company’s load to the peak load at time of all companies peak load. The calculation of Peak Load Ratio is performed using a twelve-month rolling average of the coincident peaks.
PRCHKALL	Payroll Checks Issued	Based on the number of payroll checks issued for each Business Unit
RADIOALL	Radio Usage	Based on usage of Entergy's 2-way radio system


RECDMGNT	Records Management	Based on the number of full-time and part time employees at period end, excluding the Nuclear function using records management services
SCDSPALL	Supply Chain Spending - Distribution	Based on Supply Chain Procurement Total Spending for the Distribution Function
SCFSPALL	Supply Chain Spending - Fossil	Based on Supply Chain Procurement Total Spending for the Fossil Function
SCLDTMLS	Supply Chain - Labor Dollars	Based on Supply Chain Labor Dollars for the Transformer, Meter, and Light Shops
SCMATRAN	Supply Chain Transactions in Passport	Based on the number of Supply Chain materials transactions for each Business Unit in Passport
SCPSPALL	Supply Chain Total Spending	Based on Supply Chain's Procurement Total Spending
SCPSPXNC	Supply Chain Spending - Excluding Nuclear	Based on Supply Chain Procurement Total Spending, excluding Nuclear for twelve months
SCRSPALL	Supply Chain Spending - Regulated Companies	Based on Supply Chain Procurement Total Spending for the Regulated Companies
SCTSPALL	Supply Chain Spending - Transmission	Based on Supply Chain's Procurement Total Spending for Transmission
SQFTALLC	Square Footage - All Companies	Based on square footage for all Business Units
TELPHALL	Number of Telephones	Based on number of telephones within each Business Unit
TRALINOP	Transmission Line Miles	Based on the number of miles of transmission lines, weighted for design voltage (Voltage < 400kv = 1; Voltage >400kv =2)
TRANSPND	Transmission Budgeted Capital Expenditures	Based on Transmission Budgeted Capital Expenditures
TRASUBOP	Transmission Substations	Based on the number of high voltage substations weighted for Voltage (Voltage < 500kv = 1; Voltage >= 500kv = 2)
TRSBLNOP	Transmission Line Miles/Substation	Based on two components: Transmission Line Miles (30% weighting) and the Number of High Voltage Substations (70% weighting)
VEHCLFOS	Number of Vehicles - Fossil	Based on the number of vehicles owned or leased by each Business Unit for the Fossil function only
VEHCLUSG	Number of Vehicles - Excluding Fossil and Nuclear	Based on the number of vehicles owned or leased by each Business Unit that participates in the usage based transportation allocation, excluding Fossil and Nuclear

FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report

INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

Purpose

Who Must Submit

What and Where to Submit

When to Submit

Where to Send Comments on Public Reporting Burden.

GENERAL INSTRUCTIONS

EXCERPTS FROM THE LAW

GENERAL PENALTIES

FERC FINANCIAL REPORT
FERC FORM No. 1: Annual Report of
Major Electric Utilities, Licensees
and Others and Supplemental
Form 3-Q: Quarterly Financial Report